Hydrolyzable particle compositions, treatment fluids and methods

ABSTRACT

A composition, treatment fluid and method using hydrolyzable fines. A treatment fluid, which may optionally include a high solids content fluid (HSCF) and/or an Apollonianistic solids mixture, includes a fluid loss control agent comprising a dispersion of hydrolyzable fines, optionally with one or more of a surfactant, plasticizer, dispersant, degradable particles, reactive particles and/or submicron particles selected from silicates, γ-alumina, MgO, γ-Fe2O3, TiO2, and combinations thereof.

BACKGROUND

The use of treatment fluids in general, and high solids contenttreatment fluids in particular, may benefit from very good leak offcontrol properties to inhibit fluid loss, as well as good stability,minimal settling of solids, suitable rheological properties for pumpingwith oilfield equipment, and/or good permeability of a solids pack afterplacement. Accordingly, there is a demand for further improvements inthis area of technology.

SUMMARY

In various embodiments, fine hydrolyzable particles are present and/orused in a composition, treatment fluid or method. In alternative oradditional embodiments, hydrolyzable particles are used with or withoutsubmicron particles.

BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS

FIG. 1 is a schematic diagram of a system for treating a well with ahigh solids content fluid according to an embodiment.

FIG. 2 is a plot of syringe leak-off for a tetramodal slurry as afunction of the second largest particle size at different concentrationsof the second largest particle, according to an embodiment as discussedin Example 1.

FIG. 3 is a plot of syringe leak-off for a tetramodal slurry as afunction of the third largest particle size, according to an embodimentas discussed in Example 1.

FIG. 4 illustrates a tetramodal Apollonian particle packing model basedon the Descartes circle theorem involving mutually tangent circles,according to an embodiment as discussed in Example 1.

FIG. 5 is a leak-off plot for a degradable fluid formulation before andafter thermal aging, according to an embodiment as discussed in Example3.

DETAILED DESCRIPTION

At the outset, it should be noted that in the development of any suchactual embodiment, numerous implementation—specific decisions must bemade to achieve the developer's specific goals, such as compliance withsystem related and business related constraints, which will vary fromone implementation to another. Moreover, it will be appreciated thatsuch a development effort might be complex and time consuming but wouldnevertheless be a routine undertaking for those of ordinary skill in theart having the benefit of this disclosure. In addition, the compositionused/disclosed herein can also comprise some components other than thosecited. In the summary and this detailed description, each numericalvalue should be read once as modified by the term “about” (unlessalready expressly so modified), and then read again as not so modifiedunless otherwise indicated in context. Also, in the summary and thisdetailed description, it should be understood that a concentration rangelisted or described as being useful, suitable, or the like, is intendedthat any and every concentration within the range, including the endpoints, is to be considered as having been stated. For example, “a rangeof from 1 to 10” is to be read as indicating each and every possiblenumber along the continuum between about 1 and about 10. Thus, even ifspecific data points within the range, or even no data points within therange, are explicitly identified or refer to only a few specific, it isto be understood that inventors appreciate and understand that any andall data points within the range are to be considered to have beenspecified, and that inventors possessed knowledge of the entire rangeand all points within the range.

As used in the specification and claims, “near” is inclusive of “at.”

The term “treatment”, or “treating”, refers to any subterraneanoperation that uses a fluid in conjunction with a desired functionand/or for a desired purpose. The term “treatment”, or “treating”, doesnot imply any particular action by the fluid. The term “fracturing”refers to the process and methods of breaking down a geologicalformation and creating a fracture, i.e. the rock formation around a wellbore, by pumping fluid at very high pressures (pressure above thedetermined closure pressure of the formation), in order to increaseproduction rates from a hydrocarbon reservoir. The fracturing methodsotherwise use conventional techniques known in the art.

The terms “particle” and “particle size” used herein may refer to solidsor liquids unless specified.

The term “dispersion” means a mixture of one substance dispersed inanother substance, and may include colloidal or non-colloidal systems.The term “fines dispersion” refers to a dispersion of particles havingparticle diameters of 20 microns or smaller; “fines” refers to thedispersed particles in a fines dispersion. As used herein, “colloidalsystems” consist of a dispersed phase having particle diameters of 20microns or smaller evenly dispersed in a continuous phase; “colloids”refers to the dispersed particles in a colloid system. The terms “finesemulsion”, “sol”, “hydrosol” (where the continuous phase is aqueous) and“colloidal emulsion” are used interchangeably herein to refer tocolloidal systems with solid and/or liquid particles dispersed therein.

As used herein, “emulsion” generally means any system (other than afines emulsion or a colloidal emulsion) with one liquid phase dispersedin another immiscible liquid phase, and may apply to oil-in-water andwater-in-oil emulsions. Invert emulsions refer to any water-in-oilemulsion in which oil is the continuous or external phase and water isthe dispersed or internal phase.

As used herein unless otherwise specified, particle size and particlesize distribution (PSD) mode refer to the median volume averaged size.The median size used herein may be any value understood in the art,including for example and without limitation a diameter of roughlyspherical particulates. In certain embodiments, the median size may be acharacteristic dimension, which may be a dimension considered mostdescriptive of the particles for specifying a size distribution range.

As used herein, the terms “bimodal” and “multimodal” with respect toparticle size or other variable distribution have their standardstatistical meanings. In statistics, a bimodal distribution is acontinuous probability distribution with two different modes. A mixtureis considered to be multimodal if it has two or more modes. These modesappear as distinct peaks (local maxima) in the probability densityfunction. A bimodal distribution can arise as a mixture of two differentunimodal distributions, i.e., distributions having one mode. Forexample, a bimodally distributed particle size can be defined as PSD₁with probability α or PSD₂ with probability (1−α), where PSD₁ and PSD₂are different unimodal particle sizes and 0<α<1 is a mixturecoefficient. A mixture of two unimodal distributions with differingmeans is not necessarily bimodal; however, a mixture of two normaldistributions with similar variability is considered to be bimodal iftheir respective means differ by more than the sum of their respectivestandard deviations.

As used herein, the term “packing volume factor” refers to the packedvolume fraction of a randomly packed mixture of solids having amultimodal volume-averaged particle size distribution.

As used herein, the terms “Apollonianistic,” “Apollonianistic packing,”“Apollonianistic rule,” “Apollonianistic particle size distribution,”“Apollonianistic PSD” and similar terms refer to a multimodalvolume-averaged particle size distribution with PSD modes that are notnecessarily strictly Apollonian wherein either (1) a first PSD modecomprises solids having a volume-averaged median size at least threetimes larger than the volume-average median size of at least a secondPSD mode such that a PVF of the solids mixture exceeds 0.75 or (2) thesolids mixture comprises at least three PSD modes, wherein a firstamount of particulates have a first PSD, a second amount of particulateshave a second PSD, and a third amount of particulates have a third PSD,wherein the first PSD is from two to ten times larger than the secondPSD, and wherein the second PSD is at least 1.5 times larger than thethird PSD.

As used herein, the term “bridge” refers to the occlusion of passages,e.g., the openings in a formation face, screen element or the like, toinhibit fluid flow. Thus, the term would not apply to the formation of afilter cake on a formation face or screen surface that does not inhibitfluid flow into or from the formation or through the screen. Conversely,“removing a bridge” and similar terms refer to the removal of theocclusions to restore fluid flow and also include modification of thestructure of the bridge to an extent sufficient to restore fluid flow,e.g., removing a bridge can involve forming holes through the filtercake and/or removing smaller particles from a filter cake on a screenelement to establish permeability, without physically removing thefilter cake matrix.

The term “aspect ratio” as applied herein to particles is understood asbeing the ratio of the longest dimension of the particle to the shortestdimension. A sphere or a cube has an aspect ratio of 1, for example. Anaspect ratio greater than one means the particle is elongated in onedirection. Sometimes the aspect ratio is given as less than one, meaningthat the longest dimension is used in the denominator rather than thenumerator, but is understood in the art to be equivalent to itsreciprocal where the aspect ratio is greater than one, e.g., an aspectratios of 0.5 and 2.0 are equivalent, as are 0.25 and 4.0.

The term “proppant” includes proppant or gravel used to hold fracturesopen and also includes gravel or proppant used in a gravel packingand/or a frac-pack operation.

In one embodiment, a treatment fluid comprises an solids mixturecomprising proppant slurried in a carrier fluid, and a fluid losscontrol agent comprising a hydrolyzable fines dispersion, in intimateadmixture therewith. In an embodiment, the hydrolyzable fines dispersioncomprises polyester particles. In an embodiment, the hydrolyzable finesmay have a particle size distribution mode from 0.1 to 20 microns, from0.5 to 10 microns, less than 5 microns, or from 1 to 5 microns. In anembodiment, the hydrolyzable fines dispersion comprises polyesterparticles and a surfactant. In an embodiment, the hydrolyzable finesdispersion comprises a polymer or copolymer of lactic acid, glycolicacid, or the combination thereof, and in another embodiment, the polymeror copolymer may be treated with a nonionic or anionic surfactant. In anembodiment, the hydrolyzable fines dispersion comprises a surfactant andoptionally a plasticizer. In an embodiment, the treatment fluid mayfurther comprise from 1 to 15 parts per 100 parts by weight carrierfluid of one or more of a dispersant, a surfactant, a viscosifier, adefoamer, or a combination thereof.

In an embodiment, the treatment fluid may comprise heterogeneousmicelles comprising the hydrolyzable fines and surfactant. In anembodiment, the solids mixture is Apollonianistic and may furthercomprise at least one particle size distribution mode comprisingdegradable particles, and in a further embodiment, the degradableparticles may comprise a polymer or copolymer of lactic acid, glycolicacid, or the combination thereof. In an alternative or additionalembodiment, the Apollonianistic solids mixture further comprises anacid-reactive fines particle size distribution mode. In an embodiment,the treatment fluid further comprises submicron particles selected fromsilicates, γ-alumina, MgO, γ-Fe2O3, TiO2 and combinations thereof.

In one embodiment, a treatment fluid comprises an Apollonianistic solidsmixture comprising proppant, degradable particles and submicronparticles, slurried in an aqueous carrier fluid, and in intimateadmixture therewith, a hydrolyzable polyester fines emulsion comprising1 to 5 micron particles. In an embodiment, the hydrolyzable polyestercomprises a polymer or copolymer of lactic acid, glycolic acid, or thecombination thereof. In an embodiment, the degradable particles comprisefirst and second particle size distribution modes wherein the firstparticle size distribution mode is from 1.5 to 2.5 times larger than thesecond particle size distribution mode and wherein the first PSD mode issmaller than the proppant PSD mode. In an embodiment, the carrier fluidcomprises from 0 to 3 parts by weight dispersant, from 0 to 3 parts byweight surfactant, from 0 to 3 parts by weight defoamer, and from 0 to15 parts by weight viscosifier, per 100 parts by weight carrier fluid.In an embodiment, the polylactide emulsion comprises an anionicsurfactant and optionally a plasticizer.

In another embodiment, the Apollonianistic solids mixture furthercomprises acid-reactive fines having a particle size distribution modesmaller than the second PSD mode and comprising from 1 to 20 microns.

In one embodiment, a composition comprises a carrier fluid and dispersedtherein from 5 to 100 g added per 100 ml carrier fluid of a fluid losscontrol system comprising a mixture of surfactant-treated hydrolyzablefines having a particle size distribution between 1 and 10 microns, andsubmicron particles. In an embodiment, the hydrolyzable fines comprise apolymer or copolymer of lactic acid, glycolic acid, or the combinationthereof, emulsified or stabilized with a nonionic or anionic surfactant.In an embodiment, the submicron particles comprise silicates, γ-alumina,MgO, γ-Fe2O3, TiO2 or a combination thereof.

In another embodiment of the composition, the carrier fluid is aqueous,the hydrolyzable fines comprise polylactic acid having a particle sizedistribution between about 1 and about 5 microns emulsified orstabilized with an anionic surfactant, the submicron particles comprisesilicates, γ-alumina, MgO, γ-Fe2O3, TiO2 or a combination thereof, and aweight ratio of the hydrolyzable fines to submicron particles is from1:3 to 3:1.

In an embodiment, a method comprises mixing an aqueous hydrolyzablepolyester fines emulsion and a carrier fluid to form a treatment fluid,and circulating the treatment fluid into a wellbore. In an embodiment,Apollonionistic solids are introduced into the treatment fluid. In anembodiment, a pack of the solids is formed downhole. In an embodiment,the pack comprises proppant and at least one particle size distributionmode comprising degradable particles, and the method further comprisesremoving the degradable particles from the pack to form a permeableproppant pack. In an embodiment, the method further comprises producingor injecting a fluid through the permeable proppant pack. In anembodiment, the permeable proppant pack comprises a gravel pack in anannulus between a screen and the wellbore, and in an additional oralternate embodiment, the permeable proppant pack is disposed in afracture. In an embodiment, the degradable particles comprise a polymeror copolymer of lactic acid, glycolic acid, or the combination thereof.

In one embodiment, a method, to inhibit fluid loss from a treatmentfluid comprises introducing an aqueous hydrolyzable polyester finesemulsion into the treatment fluid and introducing the treatment fluidinto a wellbore.

In one embodiment, a method, to stabilize and inhibit fluid loss from atreatment fluid, comprises introducing submicron particles and anaqueous polylactic acid fines emulsion into the treatment fluid.

The present disclosure in various embodiments describes methods,slurries and systems of fracturing, gravel packing or frac-packing awell using slurries that contain a high fraction of solids comprising anApollonianistic PSD and a fluid loss control agent comprisingpolylactide (PLA), polyglycolide (PGA), or a copolymer or mixturethereof. In one embodiment, the solids mixture comprises a plurality ofvolume-average particle size distribution (PSD) modes such that a packedvolume fraction (PVF) of the solids mixture exceeds 0.8. In anotherembodiment, the smaller PSD modes can be removed from the pack toincrease porosity and permeability for the flow of fluids through thepack.

In one embodiment, a method comprises combining a carrier fluid and asolids mixture having an Apollonianistic PSD and a fluid loss controlagent comprising polylactide (PLA), polyglycolide (PGA), or a copolymeror mixture thereof, to form a slurry, wherein the solids mixturecomprises a degradable material and includes a reactive solid;circulating the slurry through a wellbore to form a pack of the solidsin one or both of a fracture in a formation and an annulus between ascreen and the wellbore; degrading the fluid loss control agent and thedegradable material in the pack to increase porosity and permeability ofthe pack; and producing a reservoir fluid from the formation through theincreased porosity pack.

In one embodiment, the fluid loss control agent comprises emulsified orstabilized particles having a PSD from 1 to 5 microns, or from 1 to 3microns. In another embodiment, the fluid loss control agent is treatedwith a stabilizer agent comprising an anionic surfactant.

In one embodiment, the degradable material can be dissolved by changingthe pH in the solids pack. For example, alumina trihydrate particles ata neutral pH are solubilized at a high as well as at a low pH. In otherembodiments, the degradable material is soluble in basic fluids, e.g.,the degradable material is selected from amphoteric oxides, esters,coated acids and combinations thereof; and the solids mixture canfurther include a base or a base precursor that is optionally sparinglysoluble and/or encapsulated, or the solids can be contacted with a basicaqueous solution.

In further embodiments, the degradable material is soluble in acidicfluids, e.g., the degradable material is selected from oxides andhydroxides of aluminum, zinc, tin, lead, boron, silicon and iron;carbonates, sulfates, oxides and hydroxides of calcium, magnesium andbarium; and combinations thereof; and the solids mixture can furtherinclude an acid or an acid precursor that is optionally sparinglysoluble and/or encapsulated, or the solids can be contacted with anacidic aqueous solution. In one embodiment, the acid precursor isselected from the group consisting of hydrolyzable esters, acidanhydrides, acid sulfonates, acid halides and combinations thereof.

In further embodiments, the degradable material can be an encapsulatedwater- or oil-soluble solid which can be removed from the gravel orproppant pack by de-encapsulating the solid. Alternatively oradditionally the degradable material can be a water-soluble solid, andthe carrier in the slurry can be either a saturated solution of thesoluble solid, e.g. salt solids and brine, or an invert emulsion whereinthe soluble solid is dispersed in the oil phase. The soluble solid canbe removed by contacting the pack with an undersaturated aqueous mediumand/or breaking the invert emulsion.

In further embodiments, the fluid loss additive may further comprise,for example, latex dispersions, water soluble polymers, submicronparticles, and particulates with different shapes, and/or a slurrystabilizer, such as, for example, nanoparticles, polymers that hydrateat high temperatures, and high aspect ratio particles.

In another embodiment, the slurry placement may require that the slurrystay suspended for extended periods of time without settling so thatrheological characteristics are retained, for example, when thegravel-laden slurry is placed in an open hole followed by screen stab-inthere may be a delay of as much as 48 hours between slurry circulationinto the wellbore and screen stab-in while the slurry circulationworkstring is removed from the hole and the screen is tripped in. If thesolids settle prematurely, the high solids content slurry may lose itsfluid like properties and an excessive amount of force may be requiredto push the screen into the settled slurry. In an embodiment, a slurrycomprises a solids mixture comprising a plurality of PSD modes such thata PVF exceeds 0.75 or 0.8; a carrier fluid in an amount to provide anSVF less than the PVF of the solids mixture; a hydrolyzable polyesteremulsion; and optionally a stability additive to inhibit settling of thesolids mixture. In another embodiment, a method comprises combining thecarrier fluid, the solids mixture and the fluid loss control additive toform the slurry; circulating the slurry into a wellbore to deposit theslurry downhole; terminating the slurry circulation for a period of timewhile maintaining stability of the slurry to inhibit settling of thesolids mixture; and thereafter circulating the deposited slurry incontact with a surface of a screen.

In embodiments, the treatment fluid comprises submicron particles suchas, for example, silicates, γ-alumina, MgO, γ-Fe2O3, TiO2 andcombinations thereof; and may optionally further comprise hydratablepolymer particles, e.g., polymer particles having a hydrationtemperature above 60° C. such as gellan gum; high aspect ratioparticles, e.g. an aspect ratio above 6, such as, for example, flakes orfibers which may be optionally degradable such as a polymer or copolymerof lactide and/or glycolide.

The treatment fluids, compositions and methods in various embodimentsmay be used for fracturing a formation, gravel packing, frac-packing, orother operations where the treatment fluid may contain proppants orother solids in addition to the hydrolyzable fines. FIG. 1 is aschematic diagram of one embodiment of a system 100 for gravel packing,by way of illustration and not limitation. In certain embodiments, thesystem 100 includes a well 102 drilled through an overburden 104 and aformation of interest 106. The formation of interest 106 may include ahydrocarbon producing formation, a water producing formation, a targetformation for injection of a fluid, or other formation of interest knownin the art. In certain embodiments, the well 102 has a wellhead 108, anda casing 110 covering at least a portion of the wellbore. In theillustration of FIG. 1, the wellbore through the formation of interest106 is an “open hole” completion in a vertical well. Other types ofcompletions are contemplated in the present application, includingwithout limitation: a cased completion, multiple zone completions,and/or a horizontal well or well segment. The casing 110 may include acement layer (not shown) between the casing 110 and the formation(s)(104, 106). Various other features of the system 100 that are known inthe art are not shown or described herein to avoid obscuring aspects ofthe present application.

The system 100 further includes, in certain embodiments, a screen 112disposed in the wellbore. The screen 112 may include slots or holessized to prevent the flow of particles from the formation of interest106 into the well 102 or to the surface during treatment flowback orproduction of the well 102. In certain embodiments, the system 100includes a gravel pack 114 deposited between the screen 112 and theformation of interest 106.

The gravel of the gravel pack 114 may be deposited as a portion of aslurry 116 comprising particles and a carrier fluid. The carrier fluidmay in various embodiments be a brine, a fluid including a hydratablegel (e.g. a guar, other polysaccharide, hydroxyethyl-cellulose “HEC”, orother gelling agent), an oil or oil-based gel, a viscoelasticsurfactant, a fluid with a viscosifier, a foamed or “energized” fluid(e.g. a nitrogen or CO₂ based foam), an emulsion (including water or oilin the external phase), or other fluid known in the art.

In certain embodiments, the slurry 116 is pumped through the well 102 todeposit the first amount of particulates 118 and the second amount ofparticulates 120 between the screen 112 and the formation of interest106. The slurry 116 may be pumped outside the screen 112 into theformation of interest 106 until a screen-out occurs (i.e. theparticulates 118, 120 build up to the point where the pressure dropacross the gravel pack 114 prevents further pumping), the slurry 116 maybe circulated through the well 102 such that the slurry 116 passes fromoutside the screen 112 to inside the screen 112, thereby depositing theparticulates 118, 120 between the screen 112 and the formation ofinterest 106 and circulating the carrier fluid 122 to the surface. Incertain embodiments, the slurry 116 may be placed in the wellbore 102and the screen 112 lowered into the already-placed slurry 116 such thatthe particulates 118, 120 in the slurry 116 are thereby depositedbetween the screen 112 and the formation of interest 106.

In certain embodiments, the system 100 includes various devices tocontrol mixing and pumping the slurry 116. In one exemplary embodiment,the system 100 includes at least one fluid tank 124 which contains thecarrier fluid 122 and/or a base fluid utilized in the creation of thecarrier fluid 122. The exemplary embodiment further includes a gravelcarrier 126 which, in one embodiment, provides the first amount ofparticulates 118 to a blending device 128. The blending device 128prepares the final slurry 116, for example mixing the gravel fluid 122and adding the first amount of particulates 118 from the gravel carrier126, and further adding any additives, the second amount of particulates120 and/or third and/or the fluid loss control agent or any other amountof particulates. In certain embodiments, more than one particulateamount may be blended and added by the gravel carrier 126 or otherdevice. The blending device 128 further provides the slurry 116 to apumping device 130 that provides pressurized slurry 116 to the wellhead108. Other equipment configurations are understood in the art andcontemplated herein. For example, and without limitation, the system 100may include a coiled tubing unit (not shown) in place of one or morepieces of equipment and/or tubing 132 connected to the screen 112.

In various embodiments, each of the methods, processes, treatmentfluids, compositions and other aspects of the disclosure in patentapplication publication US 2011/155371 A1, which is hereby incorporatedherein by reference, may be adapted or modified for use with or toinclude a hydrolyzable fines dispersion as described herein.

In an embodiment, an Apollonianistic treatment fluid comprises a carrierfluid combined with a first, second, and third amount of particles in aslurry. The particulates in an embodiment comprise three size regimes orPSD's, wherein each size regime is larger than the next smaller sizeregime. The inclusion of varying size particulates with a highparticulate loading creates a slurry with greatly reduced settling timesrelative to a slurry with a uniform particle size.

Further, the amount of carrier fluid per unit volume of slurry can bereduced dramatically. For example, spherical particles with a uniformpacking arrangement create a packing volume fraction (PVF) of about0.74, i.e., where about 74% of the packed volume is particulate matter.Monodisperse spherical particles with a random close packing arrangementcreate a PVF of about 0.64. By contrast, an arrangement with threeparticulate sizes having average diameters, in one example, of 840microns, 150 microns, and 15 microns, respectively, creates a packedmixture of particles having a PVF of about 0.87. The base densities ofthe particles may be selected to create a final slurry density at aselected value. An increase in PVF reduces the amount of carrier fluidin the final slurry. For example, an increase from 0.64 (random packing)to just 0.80 reduces the amount of carrier fluid in a liter of slurry bynearly 50% (i.e. (36−20)/36). The reduced carrier fluid amount reducesthe amount of fluid placed in the formation of interest and the amountof viscosifier (if any) in the gravel pack 114, which all contribute toa reduction in permeability damage to the formation of interest 106 anda reduction in permeability damage to the gravel pack 114.

In certain embodiments, the slurry includes at least a first amount ofparticulates having a first average size distribution and a secondamount of particulates having a second average size distribution. Incertain embodiments, the first amount of particulates are non-deformableparticulates, e.g., proppant such as sand or ceramic beads. The averagesize distribution is determined according to any method understood inthe art, at least including a mesh screen size number (e.g., 16/30 meshsand, 20/40 mesh sand or 40/70 mesh sand), a mean particle size, and amedian particle size. The average size distributions of the first andsecond amounts of particulates are selected in an embodiment such thatthe first average size distribution is between three and fifteen timeslarger than the second average size distribution. The average sizedistributions of the first and second amounts of particulates arefurther selected to prevent migration of formation fines through thegravel pack 114 into the well 102. In certain embodiments, a larger sizedistribution (e.g. the first size distribution to the second sizedistribution and/or to a third size distribution) is a value between sixand ten times larger. Distributions between six and ten times in thisembodiment allow maximal packed volume fraction (PVF) values whileproviding a gravel pack that does not shrink, or lose pack efficiency,if smaller particle sizes are removed.

In certain embodiments, the slurry includes a third amount ofparticulates having a third average size distribution, where the secondaverage size distribution is larger than the third size distribution,for example, between 1.5 and three times larger than the third sizedistribution. For example, the first average size distribution may be amedian size of about 840 microns, the second average size distributionmay be a median size of about 150 microns, and the third average sizedistribution may be a median size of about 75 microns; or the firstaverage size distribution may be a median size of about 300 microns, thesecond average size distribution may be a median size of about 90microns, and the third average size distribution may be a median size ofabout 45 microns.

In a further embodiment, the solids mixture comprises four or more PSDmodes, wherein a first amount of particulates have a first PSD, a secondamount of particulates have a second PSD, a third amount of particulateshave a third PSD, and a fourth amount of particulates have a fourth PSD,wherein the first average size distribution is at least three timeslarger than the second average size distribution, wherein the secondaverage size distribution is larger than the third average sizedistribution, or at least 1.5 or at least three times larger than thethird average size distribution, and wherein the third average sizedistribution is larger than the fourth average size distribution, orfrom three to fifteen times larger than the fourth average sizedistribution. In one embodiment, the first average size distribution is40 mesh (422 micron) or larger, and in another comprises standard 20/40mesh (422-853 microns) gravel. In one example, the first PSD is about280 microns, the second PSD about 30 microns and the third PSD about 3microns. In one embodiment, a ratio of the total solids volume of thefirst particles to the total solids volume of the second particles isfrom about 1:1 to about 15:1, or from about 2:1 to about 10:1 or fromabout 4:1 to about 8:1; and a ratio of the total solids volume of thesecond particles to the total solids volume of the third particles isfrom about 1:10 to about 2:1, or from about 1:4 to about 1:1.

In many treatment fluids and systems it is desirable to employ a fluidloss agent that inhibits fluid loss at a formation face, screen or otherpotentially fluid permeable surface. The fluid loss agent in variousembodiments is useful in a wide variety of treatment fluids including byway of example and not limitation, drilling fluids, completion fluids,stimulating fluids, including fracing fluids, gravel packing fluids,frac-packing fluids, whether containing solids or slick water, pads,flushes, spacers, aqueous systems, non-aqueous systems, oil based,invert emulsions, and the like.

For high solids content fluids (HSCF), fluid loss control can bebeneficial since a small amount of fluid loss could render the fluidimmobile. Fluid loss control for HSCF is achieved in part byconstructing the HSCF with solid particles following a certain particlesize distribution using Apollonianistic packing parameters, where theholes created between bigger particles are filled by smaller particles.Apollonianistic packing parameters using sufficiently small particles onthe order of particulated leak-off control agents allow some degree ofleak off control to be achieved. The leak-off control in Apollonianisticfluids can also employ polymer latex materials to create a film to forman impermeable barrier. The combination of Apollonianistic solids andlatex is used in the HSCF system because the leakoff control requirementis much higher than for conventional fluids.

For Apollonianistic packing of particles to stop fluid loss, it isbeneficial for the particle sizes to extend to a few nanometer sizes.The gaps or capillaries formed in these packing systems will becomesmall enough that close to 68.9 MPa (10,000 psi) capillary pressure ispresent. This pressure can essentially stop any fluid loss. It is noteasy to have an ideal gradient of particles to achieve this good a fluidloss control. When it comes to production, it is beneficial for thesmall particles to be cleaned up (removed) to give good permeability tothe producing fluid. For the latex case, in fluid loss process, thelatex is very effective in building an impermeable layer that preventsfluid from leaking off to the formation. Since the polymer latex is usedabove its glass transition temperature, it can be pliable and deform toseal small gaps without the need to be exact in particle sizes. However,when it comes to production, the impermeable layer is very damaging,i.e. the formation fluid will not be able to produce through this layer,because it can be difficult to degrade or remove latex from the pack toregain permeability.

In the present embodiments, a hydrolyzable fines dispersion is disclosedfor both fluid loss control and cleanup of a high solid content fluidsystem. In an embodiment, the carrier fluid comprises a fluid losscontrol system comprising hydrolyzable fines, e.g., particles having aPSD from 0.1 to 20 microns or from 1 to 20 microns or from 1 to 10microns or from 1 to 5 microns, or from 1 to 3 microns. The hydrolyzablefines are, for example, a polyester polymer such as a polymer orcopolymer of lactic acid, glycolic acid or a combination thereof. In oneembodiment, the hydrolyzable fines comprise polylactide (PLA),polyglycolide (PGA) or a copolymer of combination thereof. For thepurpose of illustration and clarity, the following discussion is inreference to PLA particles by way of example and not limitation.

In an embodiment the PLA particles can include a surfactant andoptionally a plasticizer. The PLA particles may be formed by grinding orcryo-grinding of PLA pellets, and treating the particles withsurfactant, plasticizer or a combination thereof to enable dispersion,e.g., in a hydrosol or fines emulsion. Alternatively or additionally,the PLA particles can be formed by mixing a solution of the PLA in asolvent with an antisolvent or immiscible liquid (such as an aqueousphase) under high shear conditions, optionally in the presence of asurfactant, plasticizer or combination thereof, to precipitatemicroparticles in the desired PSD mode. Forty weight percent PLAemulsions often used for coatings and adhesives are commerciallyavailable under the trade designations LANDY PL-1000 (5 microns), LANDYPL-2000 (2 microns) and LANDY PL-3000 (1 micron), from Miyoshi Oil & FatCo., Ltd.

Pretreatment of the PLA particles with surfactant and/or addition of thePLA to the treatment fluid first prepared as a hydrosol or aqueous finesemulsion, e.g., a concentrated masterbatch of from 5 to 60 or from 10 to50 weight percent solids, or from 20 to 40 weight percent solids, mayfacilitate dispersion into the treatment fluid and stability of thetreatment fluid, which can be difficult where the PLA particles arehydrophobic. The surfactant can additionally or alternatively be addedto the treatment fluid separately before or after combining the PLAparticles.

Surfactants used to treat the PLA particles or form the hydrosol orfines emulsion may be cationic, zwitterionic, amphoteric, anionic,nonionic or the like. Some non-limiting examples are those cited in U.S.Pat. No. 6,435,277 (Qu et al.) and U.S. Pat. No. 6,703,352 (Dahayanakeet al.), each of which are incorporated herein by reference. In anembodiment, the PLA-treating or pretreating surfactants are nonionic oranionic. In some embodiments, the anionic surfactant is an alkylsarcosinate. The alkyl sarcosinate can generally have any number ofcarbon atoms. Alkyl sarcosinates can have about 12 to about 24 carbonatoms. The alkyl sarcosinate can have about 14 to about 18 carbon atoms.Specific examples of the number of carbon atoms include 12, 14, 16, 18,20, 22, and 24 carbon atoms. The anionic surfactant is represented bythe chemical formula:R₁CON(R₂)CH₂X

wherein R₁ is a hydrophobic chain having about 12 to about 24 carbonatoms, R₂ is hydrogen, methyl, ethyl, propyl, or butyl, and X iscarboxyl or sulfonyl. The hydrophobic chain can be an alkyl group, analkenyl group, an alkylarylalkyl group, or an alkoxyalkyl group.Specific examples of the hydrophobic chain include a tetradecyl group, ahexadecyl group, an octadecentyl group, an octadecyl group, and adocosenoic group.

In an embodiment, the nonionic surfactant may be one or more of alkylalcohol ethoxylates, alkyl phenol ethoxylates, alkyl acid ethoxylates,alkyl amine ethoxylates, sorbitan alkanoates, ethoxylated sorbitanalkanoates, or the like. The nonionic surfactant in one embodiment maybe an alkoxylate such as octyl phenol ethoxylate or a polyoxyalkylenesuch as polyethylene glycol or polypropylene glycol, or a mixture of analkoxylate or a plurality of alkoxylates with a polyoxyalkylene or aplurality of polyoxyalkylenes, e.g., a mixture of octyl phenolethoxylate and polyethylene glycol. The nonionic surfactant may alsofunction as a plasticizer which may facilitate formation of a PLA filmat the formation surface or deformation of the PLA particles to plug thepore throats or interstitial spaces within the solids pack.

As optional plasticizers in addition to any surfactant per se, the PLAfines may be treated or pretreated with polyethylene glycol,polypropylene glycol, a fatty acid ester, lactide monomer, glycolidemonomer, citric acid ester, epoxidized oil, adipate ester, azaleateester, acetylated coconut oil, or combinations thereof or the like. Theplasticizer may be blended with the PLA in the melt, as pellets, in thePLA emulsion or masterbatch, etc. The plasticizer can additionally oralternatively be added to the well treatment fluid separately before orafter introducing the PLA particles.

The PLA hydrosol or fines emulsion may incorporate the surfactant andthe optional plasticizer or blend of surfactants and/or plasticizers inan amount of about 0.02 wt % to about 5 wt % of total liquid phaseweight in the emulsion or hydrosol, or from about 0.3 wt % to about 3 wt% of total liquid phase weight.

In an embodiment, the PLA hydrosol or fines emulsion may form micellescomprising liquid PLA particles where the PLA is liquid or in solutionin a suitable solvent, for example, where the PLA solution is immisciblein the continuous phase liquid, e.g. water. The liquid-in-liquidemulsion may be stabilized with a surfactant, dispersant or the likewhich may be present within the micelles, in the continuous phase, at aninterface between the micelles and the continuous phase, or acombination thereof. The PLA hydrosol or fines emulsion added to thecarrier fluid, in one embodiment, may form heterogeneous micelles ordispersed particles or particle aggregates comprising the surfactant andthe PLA particles, and/or such heterogeneous micelles may form in thetreatment fluid. These liquid and/or heterogeneous micelles may functionas particles in the treatment fluid or proppant pack to plug porethroats in the packed solids and/or in the formation. The size of thePLA particles and/or the micelles can be selected to give the bestperformance. For example, the size of the micelles can be controlled bythe surfactant selection. The micelles and the PLA particles, especiallyplasticized PLA solids, can also have certain flexibility or pliabilityto deform and seal non-exact size or irregularly shaped pore throats.

This fluid loss control agent and system can be used in one embodimentwith HSCF systems or Apollonianistic systems, but in other embodimentscan be used in other fluids or treatment fluids.

In an embodiment, the PLA particles and micelles can be degraded,destroyed or otherwise removed after the stimulation. The PLA hydrolyzesin the presence of water at elevated temperatures, and the PLAproperties can be tailored to hydrolyze at the formation temperature andfluid chemistry in the particular downhole conditions to achievecomplete hydrolysis in the desired time frame while allowing sufficientdelay to complete placement and other steps in the stimulationoperation. The surfactant micelles can be destroyed by the presence ofhydrocarbons, such as from the formation, reaction with a de-emulsifier,degradation of the surfactant, or the like. As one example, the PLAhydrolysis products are organic acids which can interfere with and alterthe micelle structure. Acid precursors can also be present in theintermediate sized particles in the Apollonianistic solids, for example.

In some embodiments, the surfactant micelles and/or PLA particlesstabilized by surfactant are used as a fluid control agent. The micellesformed this way can be controlled by the specific surfactant used,amount of discontinuous phase etc. A wide spectrum of micelle sizes andgeometries can be achieved in this way. Since the heterogeneous micellesformed here are based on self assembly with Van der Walls force, theyare not entirely rigid. The suspended PLA particles can also be pliablewhere suitable plasticized. Under certain pressure, the micelles and/orthe PLA particles can actually deform to accommodate some shape changes.The micelles and/or particles formed in this way will help fluid losscontrol by both plugging the size-specific pore throats and beingpliable to seal holes that are not a perfect fit. Stated differently, inan embodiment the fluid loss control system has filming and particlecharacteristics similar to latex so that it can form “film-like” lowpermeability layer during stimulation treatments, and yet the resulting“film” will not have the permanence characteristics of a latex film andcan be easily removed at downhole conditions to restore permeability.

In certain embodiments, the mixing of particulates with size ratios asdescribed herein allows high particulate loadings with a low or zeroviscosifier loading. In certain embodiments, the carrier fluid includesa brine with no viscosifiers (slickwater), and the sum of the mass ofthe particulates (i.e. the first amount, second amount, and/or any thirdor other amounts combined) is at least about 2.4 kg per liter of carrierfluid 122 (20 pounds per gallon). In some embodiments the carrier fluidcomprises a hydratable gelling agent in an amount of from about 20 toabout 100 g per liter of carrier fluid. In certain embodiments, thecarrier fluid includes a hydratable gelling agent present in an amountless than about 2.4 g gel per liter of carrier fluid (20 lb gel per 1000gallons), for example less than 2.15 g/L (18 lb gel per 1000 gallons ofcarrier fluid), and the sum of the mass of the particulates exceedsabout 2.75 kg per liter (23 pounds per gallon) of carrier fluid 122. Incertain embodiments, the carrier fluid 122 includes a viscosifierpresent in an amount less than 20 lb per thousand gallons of carrierfluid 122, and the sum of the mass of the particulates exceeds about2.75 kg per liter (23 pounds per gallon) of carrier fluid 122. Incertain embodiments, the carrier fluid 122 includes a viscosifierpresent in an amount less than 2.4 g gel per liter (20 lb gel per 1000gallons) of carrier fluid 122, and the sum of the mass of theparticulates exceeds about 3.6 kg per liter (30 pounds per gallon) ofcarrier fluid 122.

In an embodiment, the solids loading in the slurry can be expressed as avolumetric ratio of solids to carrier fluid. In one embodiment, aminimum volume of the liquid (maximum volumetric solids loading)corresponds to the solids:carrier fluid volumetric ratio in the slurrycorresponding to the PVF for the solids mixture, i.e. PVF:(1−PVF), or aslight excess of liquid to impart rheological characteristics to theslurry, whereas too much excess carrier liquid might induce instabilityof the slurry (solids settling or syneresis). In one embodiment, thesolids:carrier fluid volumetric ratio is from about 40:60 up toPVF:(1−PVF), or from 45:55 to 85:15 or from 50:50 to 75:25. In otherembodiments, the volume fraction of the carrier fluid is fromstoichiometric (1−PVF) or from above stoichiometric up to 3, 2.5, 2,1.5, 1.25, 1.2, 1.1 or 1.05 times stoichiometric, or stated differently,the volumetric solids fraction is from (3PVF−2), (2.5PVF−1.5), (2PVF−1),(1.5PVF−0.5), (1.25PVF−0.25), (1.2PVF−0.2), (1.1PVF−0.1) or(1.05PVF−0.05) up to PVF.

The limits for minimum viscosifier loading and maximum particulateloading depend upon factors specific to each system that will ordinarilybe understood or controlled by those of skill in the art. For example,the settling time of the particulates in the carrier fluid, theviscosity of the carrier fluid, the intended pumping rate of the slurry,the length of the screen interval wherein the gravel pack is to beplaced, the fracture strength of the formation of interest, and otherfactors known to those of skill in the art all contribute to theviscosifier loading required in a particular application. Using brine asa carrier fluid with the layered particulate sizes, including a thirdand/or additional particulate sizes, slurries have been developed withparticulates up to or exceeding 1.92 (16 lb per gallon) or 2.4 kg perliter (20 lb per gallon) of carrier fluid, and in certain applicationsthe particulates can exceed 3.6 kg per liter (30 lb per gallon) ofcarrier fluid.

In certain embodiments, at least one of the smaller particulate sizes(i.e. the second, third, fourth, and/or fifth amount of particulates)include a degradable material. The inclusion of degradable materialallows the particulates to participate in improving suspension ofparticles in the slurry, while allowing the particles to be removed inthe gravel pack after placement, and/or to allow the particles torelease beneficial chemicals into the gravel pack after placement. Forexample, the degradation of the particulates may release chemicals thatdissolve bridging agents, break crosslinked or polymer-based carrierfluid, and/or that attack a filter cake formed.

Examples of degradable materials include, without limitation, wax,oil-soluble resin, materials soluble in hydrocarbons, lactide,glycolide, aliphatic polyester, poly(lactide), poly(glycolide),poly(ε-caprolactone), poly(orthoester), poly(hydroxybutyrate), aliphaticpolycarbonate, poly(phosphazene), poly(anhydride), poly(saccharide),dextran, cellulose, chitin, chitosan, protein, poly(amino acid),polyethylene oxide), and copolymers including polylactic acids) and/orpoly(glycolic acids), and the like. In certain embodiments, degradablematerials may include a copolymer including a first moiety that is ahydroxyl group, a carboxylic acid group, and/or a hydrocarboxylic acidgroup, and a second moiety that is a glycolic acid and/or a lactic acid.

In one embodiment, the intermediate PSD modes comprise a degradablematerial which is hydrolyzable, and in another embodiment, thehydrolyzable intermediate PSD modes comprise the same material as thehydrolyzable fines, e.g., a polymer or copolymer of lactic acid,glycolic acid or a combination thereof when the hydrolyzable finescomprise a polymer or copolymer of lactic acid, glycolic acid or acombination thereof.

In certain further embodiments, at least one of the smaller particulatesizes includes a reactive solid that reacts with a hydrolysis product ofa degradable material. For example, the second amount of particulatesmay be a degradable material and the third amount of particulates may bea material that reacts with the hydrolysis product of the second amountof particulates, enhancing the rate of degradation of the second amountof particulates. In certain embodiments, the reactive solid includesground quartz, oil soluble resin, degradable rock salt, clay, and/orzeolite or the like. In certain embodiments, the reactive solid includesmagnesium hydroxide, magnesium carbonate, magnesium calcium carbonate,calcium carbonate, aluminum hydroxide, calcium oxalate, calciumphosphate, aluminum metaphosphate, sodium zinc potassium polyphosphateglass, and/or sodium calcium magnesium polyphosphate glass or the like.The degradable materials and reactive solids that enhance degradationmay be stored on the same particle, such that reactions do not occur atthe surface but begin within the fluids at downhole conditions.

In one embodiment the reactive solid is reactive with one or more of thehydrolysis products of the hydrolyzable fines, e.g., the reactive solidis acid reactive (e.g., calcium carbonate) when the hydrolyzable finescomprise a polymer or copolymer of lactic acid, glycolic acid or acombination thereof.

In certain embodiments, the slurry comprises a degradable material andincludes a reactive solid.

In one embodiment, the first PSD mode comprises gravel and the secondPSD mode comprises alumina trihydrate particles. Alumina trihydrateparticles become soluble at elevated or depressed pH, and thus can bedegraded by changing a pH in the pack to solubilize the aluminatrihydrate particles. In another embodiment, the degradable material canbe soluble in either basic or acidic fluids, and can be degraded byincreasing or decreasing the pH, respectively, to dissolve theparticles, e.g., by contacting the solids pack with a basic aqueoussolution or an acidic aqueous solution. For example, the degradablematerial can be selected from amphoteric oxides, esters, coated acids,combinations thereof, and the like. Acid precursors which can bementioned as suitable particulates include hydrolyzable esters, acidanhydrides, acid sulfonates, acid halides, combinations thereof and thelike. As another example, the solids mixture can include a base or baseprecursor, which can in some embodiments be sparingly soluble orencapsulated. Representative classes of bases include alkali metal andammonium hydroxides, organic amines, urea, substituted urea,combinations thereof and the like. Specific representative examples ofacid soluble particulates include oxides and hydroxides of aluminum,zinc, tin, lead, boron, silicon and iron; carbonates, sulfates, oxidesand hydroxides of calcium, magnesium and barium; combinations thereofand the like.

In one embodiment, the degradable second PSD mode can be or include anencapsulated water- or oil-soluble solid, and can be degraded byde-encapsulating the soluble solid and contacting the solids pack withaqueous or hydrocarbon fluid, e.g., with reservoir fluids. In anotherembodiment, the degradable particulates can be or include awater-soluble solid and the carrier fluid can be a saturated aqueoussolution of the water-soluble solid, whereby degradation can be effectedby contacting the pack with an undersaturated aqueous medium. Forexample, the soluble particulates can be or include salt and the carrierfluid can be brine. In another embodiment, the degradable particulatescan be or include a water-soluble solid, and the carrier fluid can be aninvert emulsion wherein the water-soluble solid is dispersed in an oilphase, whereby the degradation can be effected by breaking the invertemulsion to dissolve the water-soluble solid in an aqueous medium. Theinvert emulsion can be broken, for example, by contacting the pack witha de-emulsifier, pH control agent or the like. Representative pH controlagents which may be mentioned include monoesters, polyesters, weakacids, weak bases, urea, urea derivatives, combinations thereof and thelike.

In certain embodiments, at least one of the amount of particulates(e.g., first through fifth) includes an encapsulated breaker thatreduces the viscosity of the carrier fluid after placement of the gravelpack reducing permeability damage of the pack. In certain embodiments,the carrier fluid includes an emulsion, which can be the same ordifferent as any hydrolyzable fines emulsion, and at least one of theamount of particulates includes a chemical adapted to assist in breakingthe emulsion. In certain further embodiments, the chemical adapted toassist in breaking the emulsion is encapsulated and/or included on acoated particle, such that the chemical is not released to break theemulsion until after the gravel pack is placed. In certain furtherembodiments, one or more of the amount of particulates comprises coatedparticles, such that the particles do not begin to degrade and/orrelease chemicals, breakers, solvents, and/or surfactants or the likeuntil after the gravel pack is placed. Any coating on a particle may beadapted to break down with time, temperature, fluids expected to beencountered in the wellbore, chemicals or reactive solids included onother particles and/or in the carrier fluid that are released underother mechanisms.

In one exemplary embodiment, the carrier fluid comprises an invertemulsion, the second amount of particulates includes a surfactant thatbreaks the emulsion and the second amount of particulates are coatedwith a material that breaks down in the presence of a chemical in thethird amount of particulates. In the example, the third amount ofparticulates includes a coating that degrades in the presence ofhydrocarbons (e.g. as produced from the formation of interest) thatreleases the chemical breaking down the coating on the second amount ofparticulates. Similar configurations of particles, coatings, chemicals,and the like are contemplated in the present application.

In certain embodiments, one or more of the particulates includes aformation face damage removal agent. The damage removal agent may be achemical (e.g. an acid and/or an oxidizer) structured to removeformation face damage, and/or a physical agent (e.g. particles of aspecific shape, size, or material to break an emulsion). The damageremoval agent may be any damage removal material known in the art, andmay be included in any of the particulates. Further, and withoutlimitation, the damage removal agent may be within a particle thatenters the fluid in the wellbore on dissolution, and/or is embeddedwithin a coated particle. The formation face may have permeabilitydamage from the gravel pack fluid filter cake, from a fluid loss agentin the gravel pack (other than the hydrolyzable fines dispersion), froma drilling mud filter cake, from a fluid loss agent in the drilling mud,and/or residual damage from a pill (e.g. a high viscosity pill pumpedduring drilling to stop fluid loss) pumped during drilling or completionof the wellbore. The fluid loss agent can be, for example, a latexdispersion of polyvinylidene chloride, polyvinyl acetate,polystyrene-co-butadiene; a water soluble polymer such ashydroxyethylcellulose (HEC), guar, copolymers of polyacrylamide andtheir derivatives; particulate fluid loss control agents in the sizerange of 30 nm-1 μm such as γ-alumina, fumed or colloidal silica, CaCO₃,SiO₂, TiO2, bentonite, other silicates, etc.; particulates withdifferent shapes such as glass fibers, flakes, films; and anycombination thereof or the like. In one embodiment the fluid loss agentsare colloidal.

In certain embodiments, the amount of particulates comprise particleshaving an aspect ratio of greater than or equal to one, or greater thanor equal to 6, 10, 25, 50, 100, 200 or 300. In certain embodiments,particles with a higher aspect ratio have enhanced surface area per unitvolume and enhance degradation and/or reaction rates for the particles.In certain embodiments, the amount of particulates comprises particleshaving a nano-structure, micro-structure, or mesoporous structure thatenhance the surface area of the particles. The structures of theparticles may be fractal or non-fractal. In certain embodiments, atleast one of the particulates includes a tackifying agent such as aresin-coating.

The treatment fluid, in addition to the solids, fluid loss control agentand carrier fluid may contain additional leak-off control agent,stability agent, dispersant or the like, and can contain variouscomponents and additives well known to be present in treatment fluids,including water, brine, oil, emulsion, invert emulsion, solvents,foaming or energizing agent, viscosifiers, surfactants, crosslinkers,friction reducers, breakers, accelerators, retarders, antioxidants, pHstabilizers and control agents, etc.

In embodiments, the slurry is comprised of a carrier fluid, a solidsmixture, a fluid loss control agent and a stability additive, whereinthe solids mixture comprises a plurality of PSD modes such that a packedvolume fraction (PVF) exceeds 0.75, or exceeds 0.8. The stabilityadditive helps inhibit settling of the solids mixture in the slurry, andthus maintain its rheological characteristics. This can be beneficialwhere the slurry has to be prepared in advance of use or where theslurry is placed in the wellbore with considerable delay before itcontacts the screen, e.g., where the workstring is tripped out to attachthe screen after slurry placement. The stability additive in oneembodiment comprises submicron particles, such as, for example,silicates such as silica (including fumed silica or colloidal silica),γ-alumina, MgO, γ-Fe2O3, TiO2, combinations thereof and the like.Silicates may include, for example, fumed silica, colloidal silica,diotamaceous earth and any of the silica minerals includingorthosilicates; sorosilicates; cyclosilicates; inosilicates;phyllosilicates, e.g., micas and clays such as bentonite,montmorillonite and kaolinite; tectosilicates, e.g., quartz;combinations thereof and the like. In an embodiment, the silicates arecolloidal. In one embodiment the submicron particles have a diameterbetween 5 and 200 nm, and in another embodiment the submicron particlesare colloids.

In another embodiment, the stability additive comprises hydratablepolymer particles, especially polymer particles which are hydrated atdownhole temperatures such as above 60° C., for example,heteropolysaccharides such as gellan gum. Stabilizing particles can alsoinclude particles having an aspect ratio above 6, 10, 20, 50, 100, 200,300 or the like, especially flakes or fibers comprising a polymer orcopolymer of lactic acid, glycolic acid, a combination thereof or thelike. In a particular embodiment, the slurry has a solids volumefraction (SVF) from 0.5 to 0.75, or from 0.55 to 0.7, or from 0.56 to0.68, or from 0.58 to 0.66. In various embodiments, the solids mixtureis trimodal, tetramodal, pentamodal or the like, and can remain stableand flowable for at least 48 hours.

In another embodiment, the treatment fluid may include a dispersant thatmay be helpful to improve stability and/or to remove fines from a solidspack formed from a slurry comprising at least a carrier fluid, ahydrolyzable fines dispersion and a solids mixture, e.g., anApollonianistic solids mixture. The dispersant can be present in theslurry, in another fluid used to displace the carrier fluid from theproppant pack, or in a fluid circulated and/or spotted in the wellboreafter forming the pack. In an embodiment, the dispersant comprises apolyelectrolyte, for example, polysulfonate, such as lignosulfonate,polymelamine sulfonate, polystyrene sulfonate, polynaphthalene sulfonateor the like; polycarboxylate, such as a polyacrylate having a weightaverage molecular weight less than 10,000 Daltons; combinations thereofand the like. In one embodiment, the dispersant comprises a surfactant,e.g., an anionic, cationic, amphoteric, zwitterionic or nonionicsurfactant. At low concentrations, surfactants can have a coagulatingeffect on fines, however, at sufficiently high concentrations thesurfactants are effective as fines dispersants. In general, the higherthe salinity the more dispersant that is required, especially in regardsto the ionic dispersants. Where the carrier fluid is a brine orespecially a high brine, nonionic surfactants such as polyoxyethylenes(including polyethylene glycol) may be beneficial since they are lessaffected by salinity. In general, a weight ratio between the dispersantand the fines, including the hydrolyzable fines particles, is from about1:500 to 10:90.

The fines dispersed by the dispersant in various embodiments are silica,calcium carbonate, or the like. The fines can if desired be agglomeratedin the slurry. The slurry can comprise a volume fraction of solids fromabout 0.45 up to the PVF, and a volume fraction of carrier fluid from(1−PVF) up to 0.55, or up to 2.5*(1−PVF) in one embodiment. Inembodiments the proppant PSD mode is from 100 to 2000 microns, the finesPSD mode from 1 to 20 microns, and/or the proppant PSD mode is from 18to 900 times larger than the fines PSD mode. In some embodiments, theslurry further comprises one or more intermediate PSD modes, and mayalso be selected from PSD modes from 2 to 60 times smaller than theproppant PSD mode, PSD modes from 1.1 to 60 times larger than the finesPSD mode, and combinations thereof. In a particular embodiment, theintermediate PSD modes can include a relatively larger PSD mode and arelatively smaller intermediate PSD mode, or wherein the largerintermediate PSD mode is from 2 to 15 times smaller than the proppantPSD mode and from 1.25 to 15 times larger than the smaller intermediatePSD mode, and or wherein the smaller intermediate mode is from 1.1 to 15times larger than the fines PSD mode. In a further embodiment, theslurry further comprises a middle intermediate PSD mode from 1.5 to 4times smaller than the larger intermediate PSD mode and 1.25 to 2.5times larger than the smaller PSD mode. In one embodiment, at least oneof the intermediate PSD modes is degradable, for example, the largerintermediate PSD mode.

In a further embodiment, the slurry comprises a solids mixture in acarrier fluid, wherein the solids mixture comprises first, second, thirdand fourth volume-averaged particle size distribution (PSD) modes suchthat a packed volume fraction (PVF) of the solids mixture is greaterthan 0.75, or greater than 0.80; and a solids volume fraction (SVF) ofthe slurry is less than the PVF of the solids mixture; wherein the firstPSD mode is at least three times larger than the second PSD mode, thesecond PSD mode is larger than the third PSD mode, and the third PSDmode is larger than the fourth PSD mode, and wherein at least one of thesecond and third PSD modes is less than 3 times larger than therespective third or fourth PSD mode. In one embodiment, the first PSDmode is from 3 to 10 times larger than the second PSD mode, or about 5to about 7, or about 5.4 to about 6.9, or about 5.6 to about 6.6 timeslarger than the second PSD mode, the second PSD mode is from 1.5 to 4times larger than the third PSD mode, e.g., from about 2 to about 2.4times larger than the third PSD mode. The slurry can also include afourth and/or a fifth PSD mode, wherein the fourth PSD mode is largerthan the fifth PSD mode, for example, less than 3 times larger than thefifth PSD mode. If the fourth PSD mode is present, the third PSD mode isat least 1.25 times larger than the fourth PSD mode, for example, up toabout 2.5, or about 1.8 or 1.9 times larger than the fourth PSD mode,and if the fifth PSD mode is present, the fourth PSD mode is at least1.1 times larger than the fifth PSD mode, or up to 2 times larger thanthe fifth PSD mode, or about 1.6.

In one embodiment, the first PSD mode is from about 422 microns up toabout 853 microns (20/40 mesh), the second PSD mode is from about 60microns up to about 180 microns (or from about 100 microns up to about150 microns), the third PSD mode is from about 25 microns up to about 70microns (or from about 40 microns up to about 60 microns), the fourthPSD mode if present is from about 1 micron up to about 40 microns, andthe fifth PSD mode, if present, is from about 1 micron up to about 25microns. In another embodiment, the fifth PSD mode is at least 1 micronand the first PSD mode is from about 422 microns (40 mesh) up to about853 microns (20 mesh). In an embodiment, the second PSD mode comprises atotal SVF from 5 to 30 percent (or from 10 to 20 percent, or from 10 to15 percent), the third PSD mode comprises a total SVF from 3 to 20percent (or from 3 to 10 percent), the fourth PSD mode comprises a totalSVF from 5 to 40 percent (or from 10 to 30 percent), based on a totalSVF of the first PSD mode, and the fifth PSD mode, if present, comprisesa total SVF from 1 to 40 percent, based on a total SVF of the first PSDmode. Additionally or alternatively, the second PSD mode comprises atotal SVF from 5 to 30, or 10 to 20, percent of a total SVF of the firstPSD mode; the third PSD mode comprises a total SVF from 10 to 100, or 30to 60, percent of the total SVF of the second PSD mode; the fourth PSDmode comprises a total SVF from 10 to 100, or 30 to 80, percent of thetotal SVF of the third PSD mode; and if present, the fifth PSD modecomprises a total SVF from 10 to 500, or 100 to 400, percent of thetotal SVF of the fourth PSD mode. In embodiments, the slurry can alsocomprise a fluid loss agent, a dispersant, and/or wherein at least oneof the second, third, fourth or fifth PSD modes comprises a degradablematerial.

As is evident from the figures and text presented above, as well as theexamples below, a variety of embodiments are contemplated:

-   1. A method, comprising: combining a carrier fluid, a solids mixture    and a hydrolyzable fines dispersion to form a flowable slurry,    wherein the solids mixture comprises a plurality of volume-averaged    particle size distribution (PSD) modes, wherein a first PSD mode    comprises solids having a volume-average median size at least three    times larger than the volume-average median size of a second PSD    mode such that a packed volume fraction (PVF) of the solids mixture    exceeds 0.75 or exceeds 0.8, and wherein the solids mixture, e.g.,    the second PSD mode, comprises a degradable material and includes a    reactive solid; circulating the slurry through a wellbore to form a    pack of the solids mixture having a PVF exceeding 0.75 or exceeds    0.8 in one or both of a fracture in a formation and an annulus    between a screen and the wellbore; degrading the degradable material    in the pack to increase porosity and permeability of the pack; and    producing a reservoir fluid from the formation through the increased    porosity pack.-   2. The method of embodiment 1, wherein the carrier fluid is a low    viscosity fluid free of viscosifier or comprising viscosifier in an    amount less than 2.4 g of viscosifier per liter of carrier fluid (20    lb/1000 gal).-   3. The method of embodiment 1 or 2, wherein the slurry is stable and    has a high particulate loading comprising at least 3.6 kg of the    solids mixture per liter of the carrier fluid (30 lb/gal).-   4. The method of embodiment 1, 2 or 3, wherein the first PSD mode    comprises gravel and the second PSD mode comprises alumina    trihydrate particles, and wherein the degradation comprises changing    a pH in the pack to solubilize the alumina trihydrate particles.-   5. The method of any one of embodiments 1 to 4, wherein the    degradable material is soluble in basic fluids and the degradation    comprises increasing a pH in the pack to dissolve the degradable    material.-   6. The method of embodiment 5, wherein the degradable material is    selected from the group consisting of amphoteric oxides, esters,    coated acids and combinations thereof.-   7. The method of any one of embodiments 1 to 6, wherein the solids    mixture comprises base or base precursor.-   8. The method of embodiment 7, wherein the base or base precursor is    sparingly soluble or encapsulated.-   9. The method of embodiment 7 or 8, wherein the base is selected    from the group consisting of alkali metal and ammonium hydroxides,    organic amines, urea, substituted urea and combinations thereof.-   10. The method of any one of embodiments 1 to 9, comprising    contacting the pack with a basic aqueous solution.-   11. The method of any one of embodiments 1 to 4, wherein the    degradable material is soluble in acidic fluids and the degradation    comprises decreasing a pH in the pack to dissolve the degradable    material.-   12. The method of embodiment 1 or 11, wherein the degradable    material is selected from the group consisting of oxides and    hydroxides of aluminum, zinc, tin, lead, boron, silicon and iron;    carbonates, sulfates, oxides and hydroxides of calcium, magnesium    and barium; and combinations thereof.-   13. The method of embodiment 1, 11 or 12, wherein the solids mixture    comprises an acid or acid precursor.-   14. The method of embodiment 13, wherein the acid or acid precursor    is sparingly soluble or encapsulated.-   15. The method of embodiment 13 or 14, wherein the acid precursor is    selected from the group consisting of hydrolyzable esters, acid    anhydrides, acid sulfonates, acid halides and combinations thereof.-   16. The method of any one of embodiments 1 or 11 to 15, comprising    contacting the pack with an acidic aqueous solution.-   17. The method of any one of embodiments 11 to 16, wherein the    second PSD mode comprises an encapsulated water- or oil-soluble    solid, and the degradation comprises de-encapsulating the soluble    solid.-   18. The method of any one of embodiments 11 to 17, wherein the    second PSD mode comprises a water-soluble solid and the carrier    fluid comprises a saturated aqueous solution of the water-soluble    solid, and the degradation comprises contacting the pack with an    undersaturated aqueous medium.-   19. The method of any one of embodiments 11 to 17, wherein the    second PSD mode comprises a water-soluble solid, and the carrier    fluid comprises an invert oil emulsion wherein the water-soluble    solid is dispersed in an oil phase, and the degradation comprises    breaking the emulsion to dissolve the water-soluble solid in an    aqueous medium.-   20. The method of embodiment 19, comprising contacting the pack with    a de-emulsifier to break the emulsion.-   21. The method of embodiment 19 or 20, comprising contacting the    pack with a pH control agent to break the emulsion.-   22. The method of embodiment 21, wherein the pH control agent is    selected from the group consisting of monoesters, polyesters, weak    acids, weak bases, urea, urea derivatives and combinations thereof.-   23. The method of any one of embodiments 1 to 22, wherein the    degradable material comprises a soluble material.-   24. The method of embodiment 23, wherein the carrier fluid is    saturated with respect to the soluble material.-   25. The method of embodiment 23 or 24, wherein the soluble material    comprises salt and the carrier fluid comprises brine.-   26. A composition, comprising: a carrier fluid, a solids mixture and    a hydrolyzable fines dispersion combined to form a flowable slurry,    wherein the solids mixture comprises a plurality of volume-averaged    particle size distribution (PSD) modes, wherein a first PSD mode    comprises solids having a volume-average median size at least three    times larger than the volume-average median size of a second PSD    mode such that a packed volume fraction (PVF) of the solids mixture    exceeds 0.75 or exceeds 0.8, and wherein the solids mixture, e.g.,    the second PSD mode, comprises a degradable material and includes a    reactive solid.-   27. The composition of embodiment 26, wherein the carrier fluid is a    low viscosity fluid free of viscosifier or comprising viscosifier in    an amount less than 2.4 g of viscosifier per liter of carrier fluid    (20 lb/1000 gal).-   28. The composition of embodiment 26 or 27, wherein the slurry is    stable and has a high particulate loading comprising at least 3.6 kg    of the solids mixture per liter of the carrier fluid (30 lb/gal).-   29. The composition of embodiment 26, 27 or 28, wherein the first    PSD mode comprises gravel and the second PSD mode comprises alumina    trihydrate particles.-   30. The composition of any one of embodiments 26 to 30, wherein the    degradable material is soluble in basic fluids.-   31. The composition of embodiment 30, wherein the degradable    material is selected from the group consisting of amphoteric oxides,    esters, coated acids and combinations thereof.-   32. The composition of any one of embodiments 26 to 31, wherein the    solids mixture comprises base or base precursor.-   33. The composition of embodiment 32, wherein the base or base    precursor is sparingly soluble or encapsulated.-   34. The composition of embodiment 32 or 33, wherein the base is    selected from the group consisting of alkali metal and ammonium    hydroxides, organic amines, urea, substituted urea and combinations    thereof.-   35. The composition of any one of embodiments 26 to 29, wherein the    degradable material is soluble in acidic fluids.-   36. The composition of any one of embodiments 26 to 30 or 35,    wherein the degradable material is selected from the group    consisting of oxides and hydroxides of aluminum, zinc, tin, lead,    boron, silicon and iron; carbonates, sulfates, oxides and hydroxides    of calcium, magnesium and barium; and combinations thereof.-   37. The composition of any one of embodiments 26 to 30 or 35 to 36,    wherein the solids mixture comprises an acid or acid precursor.-   38. The composition of embodiment 37, wherein the acid or acid    precursor is sparingly soluble or encapsulated.-   39. The composition of embodiment 37 or 38, wherein the acid    precursor is selected from the group consisting of hydrolyzable    esters, acid anhydrides, acid sulfonates, acid halides and    combinations thereof.-   40. The composition of any one of embodiments 26 to 39, wherein the    second PSD mode comprises an encapsulated water- or oil-soluble    solid.-   41. The composition of any one of embodiments 26 to 39, wherein the    second PSD mode comprises a water-soluble solid and the carrier    fluid comprises a saturated aqueous solution of the water-soluble    solid.-   42. The composition of embodiment 40 or 41, wherein the soluble    material comprises salt and the carrier fluid comprises brine.-   43. The composition of any one of embodiments 26 to 39, wherein the    second PSD mode comprises a water-soluble solid, and the carrier    fluid comprises an invert oil emulsion wherein the water-soluble    solid is dispersed in an oil phase.-   44. A method, comprising: combining a carrier fluid, a solids    mixture and a hydrolyzable fines dispersion to form a flowable    slurry, wherein the solids mixture comprises a plurality of    volume-averaged particle size distribution (PSD) modes such that a    packed volume fraction (PVF) of the solids mixture exceeds 0.75, or    exceeds 0.8; contacting a screen with a fluid comprising leak-off    control agent to form a bridge on the screen to inhibit fluid entry;    positioning the screen in a wellbore and circulating the slurry    through the wellbore in any order such that the solids mixture is    deposited between the screen and the wellbore; converting the    deposited solids mixture into a gravel pack to increase porosity and    permeability; removing the bridge from the screen; and producing a    reservoir fluid from the formation through the gravel pack and the    screen.-   45. The method of embodiment 44, wherein the slurry comprises the    leak-off control agent and the bridge is formed on the screen during    the circulation of the slurry.-   46. The method of embodiment 45, wherein the solids mixture    comprises three PSD modes to form the bridge on the screen, wherein    a first amount of particulates have a first PSD, a second amount of    particulates have a second PSD, and a third amount of particulates    have a third PSD, wherein the first PSD is larger than the second    PSD, and wherein second PSD is larger than the third PSD.-   47. The method of embodiment 46, wherein the first amount of    particulates comprises 40/80 mesh (178-422 microns) gravel.-   48. The method of embodiment 46 or 47, wherein the first PSD is    smaller than 40 mesh (422 microns).-   49. The method of any one of embodiments 44 to 48, wherein the    solids mixture comprises three PSD modes, wherein a first amount of    particulates have a first PSD, a second amount of particulates have    a second PSD, and a third amount of particulates have a third PSD,    wherein the first PSD is from two to ten times larger than the    second PSD, and wherein second PSD is from three to ten times larger    than the third PSD.-   50. The method of any one of embodiments 44 to 49, wherein the    leak-off control fluid comprises a spacer fluid introduced into the    wellbore.-   51. The method of embodiment 50, wherein the slurry is circulated    through the wellbore before the screen is positioned in the    wellbore, wherein the spacer fluid is positioned in the wellbore    above the slurry, and wherein the screen is passed through the    spacer fluid in the wellbore and then stabbed into the slurry.-   52. The method of embodiment 50, wherein the screen is positioned in    the wellbore before the slurry is circulated into an annulus between    the screen and the wellbore, and wherein the spacer fluid is    circulated into the annulus ahead of the slurry.-   53. The method of any one of embodiments 50 to 52, wherein the    spacer fluid and slurry are sequentially pumped through a flow    passage in the screen to a bottom end of the screen and into the    annulus.-   54. A method, comprising: combining a carrier fluid, a first amount    of particulates, a second amount of particulates, and a third amount    of particulates into a slurry; wherein the first amount of    particulates have a first average size distribution, the second    amount of particulates have a second average size distribution, and    the third amount of particulates have a third average size    distribution, wherein the first average size distribution is at    least three times larger than the second average size distribution,    and wherein the second average size distribution is larger than the    third average size distribution; wherein at least one of the second    amount of particulates and the third amount of particulates comprise    a degradable material; positioning a screen in a wellbore in a    subterranean formation and circulating the slurry through the    wellbore in any order such that the first amount of particulates,    the second amount of particulates, and the third amount of    particulates form a bridge on a surface of the screen to inhibit    fluid entry and a solids pack in an annulus between the screen    surface and a surface of the wellbore; and selectively removing from    the first amount of particulates at least a portion of the    particulates selected from the second amount of particulates, the    third amount of particulates and a combination thereof, to increase    porosity and permeability in the bridge and the solids pack for    fluid flow across the annulus and through the screen.-   55. The method of any one of embodiments 1 to 25 or 54, wherein the    screen is disposed into the wellbore before the slurry is    circulated.-   56. The method of any one of embodiments 1 to 25 or 54, wherein the    slurry is circulated into the wellbore before the screen is disposed    in the wellbore.-   57. The method of any one of embodiments 54 to 56, wherein the first    amount of particulates and the second amount of particulates have a    combined dry packing volume fraction greater than about 0.75, or    greater than 0.8.-   58. The method of any one of embodiments 54 to 57, wherein the    slurry is combined prior to circulation in the wellbore.-   59. The method of any one of embodiments 54 to 57, wherein a sum of    all particulates in the slurry exceeds thirty pounds per gallon of    carrier fluid.-   60. The method of any one of embodiments 54 to 57, wherein the    second average size distribution is at least three times larger than    the third average size distribution.-   61. The method of embodiment 60, wherein the total solids volume of    the third amount of particulates is greater than the total solids    volume of the second amount of particulates.-   62. The method of any one of embodiments 54 to 61, wherein the    slurry further includes a fourth amount of particulates having a    fourth average size distribution, and wherein the third average size    distribution is larger than the fourth average size distribution.-   63. The method of embodiment 62, wherein the slurry further includes    a fifth amount of particulates having a fifth average size    distribution, and wherein the fourth average size distribution is    larger than the fifth average size distribution.-   64. The method of any one of embodiments 54 to 63, wherein the first    average size distribution is between about six and ten times larger    than the second average size distribution.-   65. The method of any one of embodiments 54 to 64, wherein the    second average size distribution is between about 1.5 and 15 times    larger than the third average size distribution.-   66. The method of embodiment 65, wherein the slurry further includes    a fourth amount of particulates having a fourth average size    distribution, and wherein the third average size distribution is    between about 1.25 and 15 times larger than the fourth average size    distribution.-   67. The method of embodiment 66, wherein the slurry further includes    a fifth amount of particulates having a fifth average size    distribution, and wherein the fourth average size distribution is    between about 1.1 and 15 times larger than the fifth average size    distribution.-   68. A method, comprising: combining a carrier fluid, a hydrolyzable    fines dispersion, a first amount of particulates, a second amount of    particulates, a third amount of particulates and a fourth amount of    particulates into a slurry; wherein the first amount of particulates    have a first average size distribution, the second amount of    particulates have a second average size distribution, the third    amount of particulates have a third average size distribution, and    the fourth amount of particulates have a fourth average size    distribution, wherein the first average size distribution is at    least three times larger than the second average size distribution,    wherein the second average size distribution is at least three times    larger than the third average size distribution, and wherein the    third average size distribution is at least three times larger than    the fourth average size distribution; positioning a screen in a    wellbore in a subterranean formation and circulating the slurry    through the wellbore in any order such that the first amount of    particulates, the second amount of particulates, and the third    amount of particulates form a bridge on a surface of the screen to    inhibit fluid entry and a solids pack in an annulus between the    screen surface and a surface of the wellbore; selectively removing    from the first amount of particulates at least a portion of the    particulates selected from the second amount of particulates, the    third amount of particulates, the fourth amount of particulates, and    combinations thereof, to increase porosity and permeability in the    bridge and the solids pack for fluid flow across the annulus and    through the screen.-   69. The method of embodiment 68, wherein the first amount of    particulates comprises gravel.-   70. The method of embodiment 68 or 69, wherein the first average    size distribution is 40 mesh (422 μm) or larger.-   71. The method of any one of embodiments 68 to 70, wherein the first    amount of particulates comprises 20/40 mesh gravel.-   72. The method of any one of embodiments 68 to 71, wherein the    slurry further comprises a fifth amount of particulates having a    fifth average particle size distribution, wherein the fourth average    particle size distribution is at least three times larger than the    fifth average particle size distribution.-   73. The method of any one of embodiments 68 to 72, wherein the first    average size distribution is between 20 and 40 mesh (422-853 μm),    the second average size distribution is from 140 μm to 280 μm, the    third average size distribution is from 15 to 65 μm, and the fourth    average size distribution is from 1 to 10 μm.-   74. The method of any one of embodiments 68 to 73, wherein the first    average size distribution is from 3 to 15 times larger than the    second average size distribution, wherein the second average size    distribution is from 3 to 15 times larger than the third average    size distribution, and wherein the third average size distribution    is from 3 to 15 times larger than the fourth average size    distribution.-   75. The method of any one of embodiments 68 to 74, wherein at least    one of the second amount of particulates and the third amount of    particulates comprise a degradable material.-   76. The method of any one of embodiments 68 to 75, wherein the    hydrolyzable fines dispersion comprises a fluid loss agent to    inhibit leak-off from the slurry.-   77. The method of embodiment 76, wherein the slurry further    comprises a fluid loss agent selected from the group consisting of:    latex dispersions, water soluble polymers, submicron particulates,    particulates with an aspect ratio higher than 6, and combinations    thereof.-   78. The method of embodiment 76 or 77, wherein the fluid loss agent    comprises crosslinked polyvinyl alcohol microgel.-   79. The method of any one of embodiments 76 to 78, wherein the fluid    loss agent further comprises AMPS.-   80. The method of any one of embodiments 68 to 79, wherein the    slurry comprises a solids volume fraction (SVF) from 0.5 to 0.75.-   81. The method of any one of embodiments 68 to 80, wherein the total    particulates in the slurry have a packed volume fraction (PVF)    greater than the SVF.-   82. The method of any one of embodiments 1 to 25 or 44 to 81,    wherein the slurry is circulated in a horizontal portion of the    wellbore from toe to heel.-   83. The method of any one of embodiments 1 to 25 or 44 to 82,    wherein the slurry is circulated in the wellbore at a pressure less    than the fracture pressure.-   84. The method of any one of embodiments 1 to 25 or 44 to 83,    wherein the slurry is circulated in the wellbore at a rate less than    800 L/min (5 BPM).-   85. The method of any one of embodiments 1 to 25 or 44 to 84,    wherein the slurry is circulated in the wellbore through a washpipe,    wherein a screen-wellbore annulus has a radial thickness relatively    less than a radial thickness of a washpipe-screen annulus.-   86. A system, comprising: a slurry comprising a hydrolyzable fines    dispersion in a carrier fluid suspending a first amount of    particulates, a second amount of particulates, and a third amount of    particulates; wherein the first amount of particulates have a first    average size distribution, the second amount of particulates have a    second average size distribution, and the third amount of    particulates have a third average size distribution; wherein the    first average size distribution is at least three times larger than    the second average size distribution, and wherein the second average    size distribution is at least 1.5 times larger than the third    average size distribution; wherein at least one of the second amount    of particulates and the third amount of particulates comprise a    degradable material; and a tubing string and a slurry pump to    position a screen and circulate the slurry in a wellbore in a    subterranean formation in any order such that the first amount of    particulates, the second amount of particulates, and the third    amount of particulates form a bridge on a surface of the screen and    a solids pack in an annulus between the screen surface and a surface    of the wellbore, and wherein the degradable material can be    selectively removed from the first amount of particulates to    increase porosity and permeability in the solids pack for fluid flow    across the annulus and through the screen.-   87. The system of embodiment 86, wherein the first amount of    particulates and the second amount of particulates have a combined    dry packing volume fraction greater than about 0.75, or greater than    0.80.-   88. The system of embodiment 86 or 87, wherein a sum of all    particulates in the slurry exceeds thirty pounds per gallon of    carrier fluid.-   89. The system of any one of embodiments 86 to 88, wherein the total    solids volume of the third amount of particulates is greater than    the total solids volume of the second amount of particulates.-   90. The system of any one of embodiments 86 to 89, wherein the    slurry further includes a fourth amount of particulates having a    fourth average size distribution, and wherein the third average size    distribution is larger than the fourth average size distribution.-   91. The system of embodiment 90, wherein the slurry further includes    a fifth amount of particulates having a fifth average size    distribution, and wherein the fourth average size distribution is    larger than the fifth average size distribution.-   92. The system of any one of embodiments 86 to 91, wherein the first    average size distribution is between about six and ten times larger    than the second average size distribution.-   93. A method, comprising: combining a carrier fluid, a solids    mixture, a hydrolyzable fines dispersion and a stability additive to    form a slurry, wherein the solids mixture comprises a plurality of    volume-averaged particle size distribution (PSD) modes such that a    packed volume fraction (PVF) exceeds 0.75, or exceeds 0.8, wherein    the slurry comprises a solids volume fraction (SVF) less than the    PVF of the solids mixture; circulating the slurry into a wellbore to    deposit the slurry downhole; terminating the slurry circulation for    a period of time, wherein the stability additive inhibits settling    of the solids mixture; and thereafter circulating the deposited    slurry in contact with a surface of a screen.-   94. The method of embodiment 93, wherein the stability additive    comprises colloidal or submicron particles.-   95. The method of embodiment 94, wherein the submicron particles are    selected from the group consisting of silica, γ-alumina, MgO,    γ-Fe2O3, and combinations thereof, or from the group consisting of    silicates, γ-alumina, MgO, γ-Fe2O3, TiO2, and combinations thereof.-   96. The method of any one of embodiments 93 to 95, wherein the    stability additive comprises hydratable polymer particles.-   97. The method of embodiment 96, wherein the polymer particles have    a hydration temperature above 60° C.-   98. The method of embodiment 96 or 97, wherein the polymer particles    comprise heteropolysaccharide.-   99. The method of embodiment 96, 97 or 98, wherein the polymer    particles comprise gellan gum.-   100. The method of any one of embodiments 93 to 99, wherein the    stability additive comprises stabilizing particles having an aspect    ratio above 6.-   101. The method of embodiment 100, wherein the stabilizing particles    having an aspect ratio above 6 are degradable.-   102. The method of embodiment 100 or 101, wherein the stabilizing    particles having an aspect ratio above 6 comprise flakes, fibers or    a combination thereof comprising a polymer or copolymer of lactic    acid, glycolic acid, or the combination thereof.-   103. The method of any one of embodiments 93 to 102, wherein the    circulation of the deposited slurry in contact with the surface of    the screen comprises stabbing the screen into the deposited slurry.-   104. The method of any one of embodiments 93 to 103, wherein the    slurry circulation is terminated to trip a workstring from the    wellbore and trip the screen into the wellbore.-   105. The method of any one of embodiments 93 to 104, wherein the SVF    is from 0.5 to 0.75, or from 0.55 to 0.7, or from 0.56 to 0.68, or    from 0.58 to 0.66.-   106. The method of any one of embodiments 93 to 105, wherein one of    the PSD modes comprises gravel.-   107. The method of any one of embodiments 93 to 106, wherein the    solids mixture is trimodal.-   108. The method of any one of embodiments 93 to 106, wherein the    solids mixture is tetramodal.-   109. The method of any one of embodiments 93 to 106, wherein the    solids mixture is pentamodal.-   110. The method of any one of embodiments 93 to 109, further    comprising forming the solids mixture in the slurry into a pack in    an annulus between the screen and the wellbore.-   111. The method of embodiment 110, further comprising converting the    pack into a permeable gravel pack.-   112. A slurry, comprising: a solids mixture comprising a plurality    of volume-averaged particle size distribution (PSD) modes such that    a packed volume fraction (PVF) exceeds 0.75, or exceeds 0.8; a    carrier fluid in an amount to provide a solids volume fraction (SVF)    less than the PVF of the solids mixture; a hydrolyzable fines    dispersion; and a stability additive to inhibit settling of the    solids mixture.-   113. The slurry of embodiment 112, wherein the stability additive    comprises colloidal or submicron particles.-   114. The slurry of embodiment 113, wherein the submicron particles    are selected from the group consisting of silica, γ-alumina, MgO,    γ-Fe2O3, and combinations thereof, or from the group consisting of    silicates, γ-alumina, MgO, γ-Fe2O3, TiO2, and combinations thereof.-   115. The slurry of any one of embodiments 112, 113 or 114, wherein    the stability additive comprises hydratable polymer particles.-   116. The slurry of embodiment 115, wherein the polymer particles    have a hydration temperature above 60° C.-   117. The slurry of embodiment 115 or 116, wherein the polymer    particles comprise heteropolysaccharide.-   118. The slurry of any one of embodiments 115, 116 or 117, wherein    the polymer particles comprise gellan gum.-   119. The slurry of any one of embodiments 112 to 118, wherein the    stability additive comprises stabilizing particles having an aspect    ratio above 6.-   120. The slurry of embodiment 119, wherein the stabilizing particles    having an aspect ratio above 6 are degradable.-   121. The slurry of embodiment 119 or 120, wherein the stabilizing    particles having an aspect ratio above 6 comprise flakes comprising    a polymer or copolymer of lactic acid, glycolic acid, or the    combination thereof.-   122. The slurry of any one of embodiments 112 to 121, wherein the    SVF is from 0.5 to 0.75, or from 0.55 to 0.7, or from 0.56 to 0.68,    or from 0.58 to 0.66.-   123. The slurry of any one of embodiments 112 to 122, wherein one of    the PSD modes comprises gravel.-   124. The slurry of any one of embodiments 112 to 123, wherein the    solids mixture is trimodal.-   125. The slurry of any one of embodiments 112 to 123, wherein the    solids mixture is tetramodal.-   126. The slurry of any one of embodiments 112 to 123, wherein the    solids mixture is pentamodal.-   127. The slurry of any one of embodiments 112 to 126, wherein the    slurry is stable and flowable for at least 48 hours.-   128. A method to stabilize a slurry comprising a solids mixture and    a hydrolyzable fines dispersion in a carrier fluid, wherein the    solids mixture comprises from three to five volume-averaged particle    size distribution (PSD) modes such that a packed volume fraction    (PVF) exceeds 0.75, or exceeds 0.8, and wherein the slurry comprises    a solids volume fraction (SVF) less than the PVF of the solids    mixture, comprising: introducing a stability additive into the    slurry, wherein the stability additive is selected from the group    consisting of colloidal particles, hydratable polymer particles,    particles having an aspect ratio above 6, and combinations thereof.-   129. The method of embodiment 128, wherein the stability additive    comprises colloidal particles selected from the group consisting of    silica, γ-alumina, MgO, γ-Fe2O3, and combinations thereof, or from    the group consisting of silicates, γ-alumina, MgO, γ-Fe2O3, TiO2,    and combinations thereof.-   130. The method of embodiment 128 or 129, wherein the stability    additive comprises hydratable polymer particles having a hydration    temperature above 60° C.-   131. The method of embodiment 128, 129 or 130, wherein the stability    additive comprises heteropolysaccharide.-   132. The method of any one of embodiments 128 to 131, wherein the    stability additive comprises gellan gum.-   133. The method of any one of embodiments 128 to 132, wherein the    stability additive comprises stabilizing particles having an aspect    ratio above 6, wherein the stabilizing particles are degradable.-   134. The method of embodiment 133, wherein the stabilizing particles    having an aspect ratio above 6 comprise flakes comprising a polymer    or copolymer of lactic acid, glycolic acid, or the combination    thereof.-   135. The method of any one of embodiments 128 to 134, wherein the    slurry has an SVF from 0.5 to 0.75, or from 0.55 to 0.7, or from    0.56 to 0.68, or from 0.58 to 0.66.-   136. The method of any one of embodiments 128 to 135, wherein one of    the PSD modes comprises gravel.-   137. The method of any one of embodiments 128 to 136, wherein the    slurry is stable and flowable for at least 48 hours following the    introduction of the stabilizing additive into the slurry.-   138. A method, comprising: positioning a generally cylindrical    screen in a wellbore to define an annulus between the screen and the    wellbore; and passing a slurry comprising a carrier fluid, a    hydrolyzable fines dispersion and a solids mixture through the    wellbore, through a passage within the screen to a bottom end of the    screen and into the annulus to pack the solids mixture onto an outer    surface of the screen; wherein the solids mixture comprises at least    two volume-averaged particle size distribution (PSD) modes, wherein    a first PSD mode comprises solids having a volume-average median    size at least three times larger than the volume-average median size    of a second PSD mode such that a packed volume fraction (PVF) of the    solids mixture exceeds 0.75 or exceeds 0.8.-   139. The method of embodiment 138, wherein the screen positioning    employs a workstring comprising drill pipe, packer assembly, and a    washpipe, and further comprising connecting the washpipe to a bottom    end of the screen, pumping the slurry down the drill pipe through    the washpipe and out of the bottom end into the annulus, and further    comprising, after pumping the slurry into the annulus, setting the    packer and removing the washpipe.-   140. The method of embodiment 138 or 139, wherein the annulus has a    radial thickness (wellbore inside radius minus screen outside    radius) less than 25 mm.-   141. The method of any one of embodiments 138 to 140, wherein the    slurry is circulated in the annulus at a pressure less than the    fracture pressure, or at a rate of less than 800 L/min (5 BPM).-   142. The method of embodiment 138, wherein the screen positioning    employs a workstring comprising drill pipe, packer assembly,    washpipe, the screen and an end cap comprising a port to allow the    washpipe to connect to a bottom of the assembly, and further    comprising setting the packer, pumping the slurry down the drill    pipe through the washpipe and out of the bottom of the assembly into    the annulus to build up pressure in the annulus greater than a    fracture pressure to fracture the formation, and thereafter removing    the drill pipe and the washpipe from the wellbore.-   143. The method of embodiment 138, wherein the screen positioning    employs a production assembly comprising production tubing, the    screen and a packer, wherein the screen is coated with a degradable    material to inhibit inflow, wherein following the screen    positioning, the slurry is pumped down the production tubing through    the central flow passage, out of the distal end into the annulus,    and further comprising, after pumping the slurry into the annulus,    setting the packer, degrading the degradable material for inflow    into the screen and producing reservoir fluid through the production    tubing.-   144. The method of embodiment 138, wherein the screen positioning    employs a production assembly comprising production tubing, the    screen and a packer, wherein the screen contains a degradable    material within a base pipe to inhibit inflow, wherein following the    screen positioning, the slurry is pumped down the production tubing    through the central flow passage, out of the distal end into the    annulus, and further comprising, after pumping the slurry into the    annulus, setting the packer, degrading the degradable material for    inflow and producing reservoir fluid through the production tubing.-   145. The method of embodiment 138, wherein the screen positioning    employs a production assembly comprising production tubing, the    screen, a packer, and a mechanical inflow device to selectively    inhibit or allow inflow, wherein following the screen positioning,    the slurry is pumped down the production tubing through the central    flow passage, out of the distal end into the annulus, and further    comprising, after pumping the slurry into the annulus, setting the    packer, activating the inflow device to allow inflow into the screen    and producing reservoir fluid through the production tubing.-   146. The method of embodiment 145 wherein the inflow device is    remotely activated.-   147. The method of embodiment 145 or 146, wherein the inflow device    is activated by a timing device at a prescribed time after the    production assembly is run in hole.-   148. The method of any one of embodiments 138 to 147, further    comprising setting a chemical packer in an annulus between the    wellbore and a tubing connected to the screen.-   149. The method of embodiment 148, wherein the chemical packer is    run ahead of the slurry.-   150. The method of any one of embodiments 138 to 149, further    comprising setting a plurality of spaced chemical packers in the    screen-wellbore annulus and optionally in an annulus between the    wellbore and a tubing connected to the screen, to create zonal    isolation.-   151. The method of any one of embodiments 148 to 150, wherein the    chemical packer is introduced to the tubing-wellbore annulus through    a diversion port above the screen.-   152. The method of embodiment 138, wherein the screen positioning    employs a drilling assembly comprising a drill string, the screen, a    liner packer and a drilling and measurement assembly comprising a    drill bit, the screen positioning comprising drilling a final length    of hole to place the screen, the slurry circulation comprising    pumping the slurry through the drilling assembly out of the drill    bit and into the annulus, and further comprising, after pumping the    slurry into the annulus, setting the liner packer, removing the    drill string and abandoning the bit downhole.-   153. The method of embodiment 152, further comprising pumping a    plugging material to follow the slurry and seal off a bottom of the    wellbore.-   154. The method of embodiment 138, wherein the screen positioning    employs a drilling assembly comprising a drill string, the screen, a    liner packer and a drilling and measurement assembly comprising a    drill bit, the screen positioning comprising drilling a final length    of hole to place the screen, and further comprising setting the    packer, pumping the slurry through the drilling assembly out of the    drill bit and into the annulus to build up pressure in the annulus    greater than a fracture pressure to fracture the formation, removing    the drill string and abandoning the bit downhole.-   155. The method of embodiment 138, wherein the screen positioning    employs a drilling assembly comprising a drill string, the screen    and a drilling and measurement assembly comprising a drill bit, the    screen positioning comprising drilling a final length of hole to    place the screen, the slurry circulation comprising pumping a    chemical packer ahead of the slurry through the drilling assembly    out of the drill bit and into the annulus, and further comprising,    after pumping the chemical packer and the slurry into the annulus,    setting the chemical packer, removing the drill string and    abandoning the bit downhole.-   156. The method of embodiment 155, further comprising pumping cement    ahead of the chemical packer to place cement around any free casing.-   157. The method of any one of embodiments 138 to 156, further    comprising transforming the packed solids mixture into a permeable    gravel pack.-   158. A method, comprising: combining a carrier fluid, a hydrolyzable    fines dispersion and a solids mixture to form a slurry, wherein the    solids mixture comprises a plurality of volume-averaged particle    size distribution (PSD) modes such that a packed volume fraction    (PVF) exceeds 0.75, or exceeds 0.8, wherein the solids mixture    comprises at least a proppant PSD mode and a non-hydrolyzable fines    PSD mode; circulating the slurry through a wellbore to form a    proppant pack from depositing the solids mixture in one or both of a    fracture in a formation and an annulus between a screen and the    wellbore; contacting non-hydrolyzable fines in the pack with a    dispersant; passing fluid through the pack to remove    non-hydrolyzable fines from the pack.-   159. The method of embodiment 158, wherein the dispersant is present    in the slurry.-   160. The method of embodiment 158, wherein contacting the    non-hydrolyzable fines with the dispersant comprises displacing the    carrier fluid from the proppant pack with another fluid comprising    the dispersant.-   161. The method of any one of embodiments 158 to 160, wherein    contacting the non-hydrolyzable fines with the dispersant comprises    circulating a fluid comprising the dispersant in the wellbore after    forming the pack.-   162. The method of any one of embodiments 158 to 161, wherein    contacting the non-hydrolyzable fines with the dispersant comprises    spotting a fluid comprising the dispersant in contact with the pack    after forming the pack.-   163. The method of any one of embodiments 158 to 162, wherein the    dispersant comprises a polyelectrolyte.-   164. The method of any one of embodiments 158 to 163, wherein the    dispersant comprises polysulfonate, polycarboxylate or a combination    thereof.-   165. The method of any one of embodiments 158 to 164, wherein the    dispersant comprises lignosulfonate, polymelamine sulfonate,    polystyrene sulfonate, polynaphthalene sulfonate or a combination    thereof.-   166. The method of any one of embodiments 158 to 165, wherein the    dispersant comprises polynaphthalene sulfonate.-   166A. The method of any one of embodiments 158 to 166, wherein the    dispersant comprises polyacrylate having a weight average molecular    weight less than 10,000 Daltons-   167. The method of any one of embodiments 158 to 166A, wherein the    dispersant comprises an anionic, cationic, amphoteric or    zwitterionic surfactant.-   168. The method of any one of embodiments 158 to 167, wherein the    dispersant comprises a nonionic surfactant and the carrier fluid    optionally comprises brine.-   169. The method of any one of embodiments 158 to 168, wherein a    weight ratio of dispersant to fines is from about 1:500 to about    10:90.-   170. The method of any one of embodiments 158 to 169, wherein the    non-hydrolyzable fines comprise silica.-   171. The method of any one of embodiments 158 to 170, wherein the    non-hydrolyzable fines comprise calcium carbonate.-   172. The method of any one of embodiments 158 to 171, wherein the    non-hydrolyzable fines are agglomerated in the slurry.-   173. The method of any one of embodiments 158 to 172, wherein the    slurry comprises a volume fraction of solids of from about 0.45 up    to the PVF.-   174. The method of any one of embodiments 158 to 173, wherein the    slurry comprises a volume fraction of carrier fluid from (1−PVF) to    0.55, or to 2.5*(1−PVF).-   175. The method of any one of embodiments 158 to 174, wherein the    proppant PSD mode is from 100 to 2000 microns and the    non-hydrolyzable fines PSD mode is from 1 to 20 microns.-   176. The method of any one of embodiments 158 to 175, wherein the    proppant PSD mode is from 18 to 900 times larger than the    non-hydrolyzable fines PSD mode.-   177. The method of any one of embodiments 158 to 176, wherein the    slurry further comprises one or more intermediate PSD modes selected    from the group consisting of PSD modes from 2 to 60 times smaller    than the proppant PSD mode, PSD modes from 1.1 to 60 times larger    than the non-hydrolyzable fines PSD mode, and combinations thereof.-   178. The method of embodiment 177, wherein at least one of the    intermediate PSD modes is degradable, and further comprising    degrading the at least one degradable intermediate PSD mode after    forming the pack.-   179. The method of any one of embodiments 177 to 178, wherein the    intermediate PSD modes include a relatively larger PSD mode and a    relatively smaller intermediate PSD mode, wherein the larger    intermediate PSD mode is from 2 to 15 times smaller than the    proppant PSD mode and from 1.25 to 15 times larger than the smaller    intermediate PSD mode, and wherein the smaller intermediate mode is    from 1.1 to 15 times larger than the non-hydrolyzable fines PSD    mode.-   179A. The method of embodiment 179, further comprising a middle    intermediate PSD mode from 1.5 to 4 times smaller than the larger    intermediate PSD mode and 1.25 to 2.5 times larger than the smaller    PSD mode.-   180. The method of embodiment 179 or 179A, wherein the larger    intermediate PSD mode is degradable, and further comprising    degrading the larger intermediate PSD mode after forming the pack.-   181. The method of any one of embodiments 158 to 180, wherein at    least 70 percent of the fines are removed from the pack.-   182. The method of any one of embodiments 158 to 181, further    comprising producing reservoir fluid through the cleaned pack into    the wellbore.-   183. The method of any one of embodiments 158 to 182, comprising    gravel packing wherein the slurry is circulated in the wellbore at a    rate less than about 800 L/min (5 BPM), or to avoid fracturing the    formation.-   184. The method of any one of embodiments 158 to 183, wherein the    carrier fluid is a low viscosity fluid free of viscosifier or    comprising viscosifier in an amount less than 2.4 g of viscosifier    per liter of carrier fluid (20 lb/1000 gal).-   185. A system, comprising: a well bore in fluid communication with a    subterranean formation; a gravel packing slurry comprising a carrier    fluid, a hydrolyzable fines dispersion and a solids mixture, wherein    the solids mixture comprises a plurality of volume-averaged particle    size distribution (PSD) modes such that a packed volume fraction    (PVF) exceeds 0.75, or exceeds 0.8, wherein the solids mixture    comprises at least a proppant PSD mode and a non-hydrolyzable fines    PSD mode; a pump to circulate the slurry in the wellbore to deposit    the solids mixture and form a proppant pack in one or both of a    fracture in the formation and an annulus between a screen and the    formation; and a dispersant source effective to facilitate fines    flowback from the pack.-   186. The system of embodiment 185, wherein the dispersant is present    in the slurry.-   187. The system of embodiment 185 or 186, wherein the dispersant    source comprises a dispersant circulation or spotting fluid.-   188. The system of any one of embodiments 185 to 187, wherein the    dispersant comprises a polyelectrolyte.-   189. The system of any one of embodiments 185 to 188, wherein the    dispersant comprises polysulfonate, polycarboxylate or a combination    thereof.-   190. The system of any one of embodiments 185 to 189, wherein the    dispersant comprises a lignosulfonate, polymelamine sulfonate,    polystyrene sulfonate, polynaphthalene sulfonate or a combination    thereof.-   191. The system of any one of embodiments 185 to 190, wherein the    dispersant comprises polynaphthalene sulfonate.-   191A. The system of any one of embodiments 185 to 191, wherein the    dispersant comprises polyacrylate having a weight average molecular    weight less than 10,000 Daltons-   192. The system of any one of embodiments 185 to 191A, wherein the    dispersant comprises an anionic, cationic, amphoteric or    zwitterionic surfactant.-   193. The system of any one of embodiments 185 to 192, wherein the    dispersant comprises a nonionic surfactant and the carrier fluid    optionally comprises brine.-   194. The system of any one of embodiments 185 to 193, wherein a    weight ratio of dispersant to non-hydrolyzable fines is from about    1:500 to about 10:90.-   195. The system of any one of embodiments 185 to 194, wherein the    non-hydrolyzable fines comprise silica.-   196. The system of any one of embodiments 185 to 195, wherein the    non-hydrolyzable fines comprise calcium carbonate.-   197. The system of any one of embodiments 185 to 196, wherein the    non-hydrolyzable fines are agglomerated in the slurry.-   198. The system of any one of embodiments 185 to 197, wherein the    slurry comprises a volume fraction of solids of from about 0.45 up    to the PVF.-   199. The system of any one of embodiments 185 to 198, wherein the    slurry comprises a volume fraction of carrier fluid from (1−PVF) to    0.55, or up to 2.5*(1−PVF).-   200. The system of any one of embodiments 185 to 199, wherein the    proppant PSD mode is from 100 to 2000 microns and the    non-hydrolyzable fines PSD mode is from 1 to 20 microns.-   201. The system of any one of embodiments 185 to 200, wherein the    proppant PSD mode is from 18 to 900 times larger than the    non-hydrolyzable fines PSD mode.-   202. The system of any one of embodiments 185 to 201, wherein the    slurry further comprises one or more intermediate PSD modes selected    from the group consisting of: PSD modes from 2 to 60 times smaller    than the proppant PSD mode, PSD modes from 1.1 to 60 times larger    than the fines PSD mode, and combinations thereof.-   203. The system of embodiment 202, wherein at least one of the    intermediate PSD modes is degradable.-   204. The system of embodiment 202 or 203, wherein the intermediate    PSD modes include a relatively larger intermediate PSD mode and a    relatively smaller intermediate PSD mode, or wherein the larger    intermediate PSD mode is from 2 to 15 times smaller than the    proppant PSD mode and from 1.25 to 15 times larger than the smaller    intermediate PSD mode, and wherein the smaller intermediate mode is    from 1.1 to 15 times larger than the non-hydrolyzable fines PSD    mode.-   205. The system of embodiment 204, further comprising a middle    intermediate PSD mode from 1.5 to 4 times smaller than the larger    intermediate PSD mode and 1.25 to 2.5 times larger than the smaller    PSD mode.-   206. The system of embodiment 204 or 205, wherein the relatively    larger intermediate PSD mode is degradable.-   207. The system of any one of embodiments 185 to 206, wherein the    carrier fluid is a low viscosity fluid free of viscosifier or    comprising viscosifier in an amount less than 2.4 g of viscosifier    per liter of carrier fluid (20 lb/1000 gal).-   208. A slurry, comprising: a solids mixture and a hydrolyzable fines    dispersion in a carrier fluid, wherein the solids mixture comprises    first, second, third and fourth volume-averaged particle size    distribution (PSD) modes such that a packed volume fraction (PVF) of    the solids mixture is greater than 0.75, or greater than 0.80; a    solids volume fraction (SVF) of the slurry less than the PVF of the    solids mixture; wherein the first PSD mode is at least three times    larger than the second PSD mode, the second PSD mode is larger than    the third PSD mode, and the third PSD mode is larger than the fourth    PSD mode, and wherein at least one of the second and third PSD modes    is less than 3 times larger than the respective third or fourth PSD    mode.-   209. The slurry of embodiment 208, wherein the solids mixture    further comprises a fifth PSD mode, wherein the fourth PSD mode is    larger than the fifth PSD mode and optionally less than 3 times    larger than the fifth PSD mode.-   210. The slurry of embodiment 208, wherein the first PSD mode is    from 3 to 10 times larger than the second PSD mode (or about 5 to    about 7, or about 5.4 to about 6.9, or about 5.6 to about 6.6 times    larger than the second PSD mode), the second PSD mode is from 1.5 to    4 times larger than the third PSD mode (or from about 2 to about 2.4    times larger than the third PSD mode), and the third PSD mode is at    least 1.25 times larger than the fourth PSD mode.-   211. The slurry of embodiment 210, wherein the solids mixture    further comprises a fifth PSD mode, wherein the fourth PSD mode is    at least 1.1 times larger than the fifth PSD mode.-   212. The slurry of any one of embodiments 208 to 211, wherein the    first PSD mode is from about 422 microns up to about 853 microns    (20/40 mesh), the second PSD mode is from about 60 microns up to    about 180 microns (or from about 100 microns up to about 150    microns), the third PSD mode is from about 25 microns up to about 70    microns (or from about 40 microns up to about 60 microns), and the    fourth PSD mode is from about 1 micron up to about 40 microns.-   213. The slurry of embodiment 212, wherein the solids mixture    further comprises a fifth PSD mode smaller than the fourth PSD mode,    wherein the fifth PSD mode is from about 1 micron up to about 25    microns.-   214. The slurry of any one of embodiments 208 to 213, wherein the    solids mixture further comprises a fifth PSD mode smaller than the    fourth PSD mode, wherein the fifth PSD mode is at least 1 micron and    the first PSD mode is from about 422 microns (40 mesh) up to about    853 microns (20 mesh).-   215. The slurry of any one of embodiments 208 to 214, wherein the    second PSD mode comprises a total SVF from 5 to 30 percent (or from    10 to 20 percent, or from 10 to 15 percent), the third PSD mode    comprises a total SVF from 3 to 20 percent (or from 3 to 10    percent), and the fourth PSD mode comprises a total SVF from 5 to 40    percent (or from 10 to 30 percent), based on a total SVF of the    first PSD mode.-   216. The slurry of embodiment 215, wherein the solids mixture    further comprises a fifth PSD mode smaller than the fourth PSD mode,    wherein the fifth PSD mode comprises a total SVF from 1 to 40    percent, based on a total SVF of the first PSD mode.-   217. The slurry of any one of embodiments 208 to 216, wherein the    second PSD mode comprises a total SVF from 5 to 30, or 10 to 20,    percent of a total SVF of the first PSD mode; the third PSD mode    comprises a total SVF from 10 to 100, or 30 to 60, percent of the    total SVF of the second PSD mode; and the fourth PSD mode comprises    a total SVF from 10 to 500, or 100 to 400, percent of the total SVF    of the third PSD mode.-   218. The slurry of embodiment 217, wherein the solids mixture    further comprises a fifth PSD mode, wherein the fifth PSD mode    comprises a total SVF from 20 to 100, or 30 to 80, percent of the    total SVF of the fourth PSD mode.-   219. The slurry of any one of embodiments 208 to 218, wherein the    first PSD mode comprises a total SVF from 60 to 80 percent of the    total SVF of the solids mixture.-   220. The slurry of embodiment 208, wherein the first PSD mode is    between 20 and 40 mesh (422-853 μm), the second PSD mode is from    about 100 μm to about 280 μm and, the third PSD mode is from about    15 μm to 60 μm, and the fourth PSD mode is from about 1 μm to 25 μm.-   221. The slurry of embodiment 220, further comprising a fifth PSD    mode wherein the fourth PSD mode is larger than the fifth PSD mode.-   222. The slurry of any one of embodiments 208 to 221, wherein the    hydrolyzable fines dispersion comprises a fluid loss agent to    inhibit leak-off from the slurry.-   223. The slurry of embodiment 222, wherein the fluid loss agent    further comprises one selected from the group consisting of: latex    dispersions, water soluble polymers, submicron particulates,    particulates with an aspect ratio higher than 6, and combinations    thereof.-   224. The slurry of embodiment 222 or 223, wherein the fluid loss    agent further comprises crosslinked polyvinyl alcohol microgel.-   225. The slurry of any one of embodiments 222 to 224, wherein the    fluid loss agent further comprises AMPS.-   226. The slurry of any one of embodiments 208 to 225, wherein the    solids mixture comprises a PVF of at least 0.85, 0.90, 0.95, 0.96,    0.97, 0.98 or 0.99.-   227. The slurry of any one of embodiments 208 to 226, wherein at    least one of the second, third or fourth PSD modes comprises a    degradable material.-   228. The slurry of embodiment 227, wherein the solids mixture    comprises a reactive material.-   229. The slurry of any one of embodiments 208 to 226, wherein the    solids mixture further comprises a fifth PSD mode, wherein at least    one of the second, third, fourth or fifth PSD modes comprises a    degradable material.-   230. The slurry of embodiment 229, wherein the solids mixture    comprises a reactive material.-   231. A method, comprising: combining a solids mixture and a carrier    fluid to form the slurry of any one of embodiments 208 to 230; and    positioning a screen in a wellbore and circulating the slurry    through the wellbore in any order such that the solids mixture is    deposited between the screen and the wellbore.-   232. The method of embodiment 231, wherein the slurry is circulated    in a horizontal portion of the wellbore from toe to heel.-   233. The method of any one of embodiments 231 to 232, wherein the    slurry is circulated in the wellbore at a pressure less than the    fracture pressure.-   234. The method of any one of embodiments 231 to 233, wherein the    slurry is circulated in the wellbore at a rate of less than 800    L/min (5 BPM).-   235. The method of claim any one of embodiments 231 to 234, wherein    the slurry is circulated in the wellbore through a washpipe, wherein    a screen-wellbore annulus has a radial thickness relatively less    than a radial thickness of a washpipe-screen annulus.-   236. The method of any one of embodiments 231 to 256, wherein the    slurry is circulated in a horizontal portion of the wellbore from    toe to heel.-   237. The method of any one of embodiments 231 to 257, wherein the    hydrolyzable fines and the first, second, third, fourth and any    other particulates in the slurry are formed into a pack in an    annulus between the screen and the wellbore.-   238. The method of embodiment 258, further comprising converting the    pack into a permeable gravel pack comprising the first amount of    particulates.-   239. A system, comprising: a well bore in fluid communication with a    subterranean formation; a gravel packing slurry comprising the    slurry of any one of embodiments 208 to 230; a pump to circulate the    slurry in the wellbore and a workstring to position a screen in the    wellbore in either order to deposit the slurry in one or both of a    fracture in the formation and an annulus between the screen and the    formation; and means for converting the deposited slurry to a gravel    pack.-   240. The system of embodiments 239, further comprising a washpipe to    circulate the slurry through the screen, wherein a screen-wellbore    annulus has a radial thickness relatively less than a radial    thickness of a washpipe-screen annulus.-   241. A system, comprising: a well bore in fluid communication with a    subterranean formation; a gravel packing slurry comprising a carrier    fluid, a hydrolyzable fines dispersion and a solids mixture, wherein    the solids mixture comprises a plurality of volume-averaged particle    size distribution (PSD) modes such that a packed volume fraction    (PVF) exceeds 0.75, or exceeds 0.8, wherein the solids mixture    comprises at least a proppant PSD mode, a non-hydrolyzable fines PSD    mode, and one or more intermediate PSD modes selected from the group    consisting of: PSD modes from 2 to 60 times smaller than the    proppant PSD mode, PSD modes from 1.1 to 60 times larger than the    non-hydrolyzable fines PSD mode, and combinations thereof, wherein    any two of the proppant, intermediate and non-hydrolyzable fines PSD    modes have a size ratio less than 3; and a pump to circulate the    slurry in the wellbore to deposit the solids mixture and form a    proppant pack in one or both of a fracture in the formation and an    annulus between a screen and the formation.-   242. The system of embodiment 241, wherein the intermediate PSD    modes include a relatively larger intermediate PSD mode and a    relatively smaller intermediate PSD mode, or wherein the larger    intermediate PSD mode is from 2 to 15 times smaller than the    proppant PSD mode and from 1.25 to 15 times larger than the smaller    intermediate PSD mode, and wherein the smaller intermediate mode is    from 1.1 to 15 times larger than the non-hydrolyzable fines PSD    mode.-   243. The system of embodiment 241, further comprising a middle    intermediate PSD mode from 1.5 to 4 times smaller than the larger    intermediate PSD mode and 1.25 to 2.5 times larger than the smaller    PSD mode.-   244. The system of embodiment 242 or 243, wherein at least one    intermediate PSD mode is degradable, for example, the relatively    larger PSD mode.-   245. A method, comprising: combining a carrier fluid, a hydrolyzable    fines dispersion and a solids mixture to form a slurry, wherein the    solids mixture comprises a plurality of volume-averaged particle    size distribution (PSD) modes such that a packed volume fraction    (PVF) exceeds 0.75, or exceeds 0.8, wherein the solids mixture    comprises at least a proppant PSD mode, a non-hydrolyzable fines PSD    mode, and one or more intermediate PSD modes selected from the group    consisting of: PSD modes from 2 to 60 times smaller than the    proppant PSD mode, PSD modes from 1.1 to 60 times larger than the    non-hydrolyzable fines PSD mode, and combinations thereof, wherein    any two of the proppant, intermediate and fines PSD modes have a    size ratio less than 3; and circulating the slurry through a    wellbore to form a proppant pack from depositing the solids mixture    in one or both of a fracture in a formation and an annulus between a    screen and the wellbore.-   246. The method of embodiment 245, wherein the intermediate PSD    modes include a relatively larger intermediate PSD mode and a    relatively smaller intermediate PSD mode, or wherein the larger    intermediate PSD mode is from 2 to 15 times smaller than the    proppant PSD mode and from 1.25 to 15 times larger than the smaller    intermediate PSD mode, and wherein the smaller intermediate mode is    from 1.1 to 15 times larger than the non-hydrolyzable fines PSD    mode.-   247. The method of embodiment 246, further comprising a middle    intermediate PSD mode from 1.5 to 4 times smaller than the larger    intermediate PSD mode and 1.25 to 2.5 times larger than the smaller    PSD mode.-   248. The method of embodiment 246 or 247, wherein at least one    intermediate PSD mode is degradable, for example the relatively    larger PSD mode.-   249. A treatment fluid, comprising a solids mixture slurried in a    carrier fluid; and a fluid loss control agent comprising a    hydrolyzable fines dispersion in intimate admixture therewith.-   250. The treatment fluid of embodiment 249, wherein the    Apollonianistic solids mixture comprises proppant.-   251. The treatment fluid of embodiment 249 or embodiment 250,    wherein the solids mixture is Apollonianistic.-   251A. The treatment fluid of any one of embodiments 249 to 251,    wherein the solids mixture comprises at least one particle size    distribution mode comprising degradable particles.-   251B. The treatment fluid of embodiment 251A, wherein the at least    one particle size distribution mode comprising degradable particles    has a particle size distribution greater than 20 microns.-   252. The treatment fluid of embodiment 251A or 251B, wherein the    degradable particles comprise a polymer or copolymer of lactic acid,    glycolic acid, or the combination thereof.-   253. The treatment fluid of any one of embodiments 249 to 252,    wherein the hydrolyzable fines dispersion comprises polyester    particles having a particle size distribution mode from 0.1 to 20    microns.-   254. The treatment fluid of any one of embodiments 249 to 253,    wherein the hydrolyzable fines dispersion comprises polyester    particles and a surfactant.-   255. The treatment fluid of any one of embodiments 249 to 254,    wherein the hydrolyzable fines dispersion comprises a polymer or    copolymer of lactic acid, glycolic acid, or the combination thereof,    treated with a nonionic or anionic surfactant.-   256. The treatment fluid of any one of embodiments 249 to 255,    wherein the hydrolyzable fines dispersion comprises a surfactant and    optionally a plasticizer.-   257. The treatment fluid of any one of embodiments 249 to 256,    further comprising submicron particles selected from silica,    γ-alumina, MgO, γ-Fe2O3, and combinations thereof, or from the group    consisting of silicates, γ-alumina, MgO, γ-Fe2O3, TiO2, and    combinations thereof.-   258. The treatment fluid of any one of embodiments 249 to 257,    further comprising from 1 to 15 parts per 100 parts by weight    carrier fluid of one or more of a dispersant, a surfactant    (including or in addition to any surfactant in the hydrolyzable    fines dispersion), a viscosifier, a defoamer, or a combination    thereof.-   259. The treatment fluid of any one of embodiments 249 to 258,    wherein the solids mixture further comprises an acid-reactive fines    particle size distribution mode.-   260. A treatment fluid, comprising: an Apollonianistic solids    mixture comprising proppant, degradable particles and submicron    particles, slurried in an aqueous carrier fluid, wherein the    degradable particles comprise a polymer or copolymer of lactic acid,    glycolic acid, or a combination thereof, wherein the degradable    particles comprise first and second particle size distribution modes    wherein the first particle size distribution mode is from 1.5 to 2.5    times larger than the second particle size distribution mode and    wherein the first PSD mode is smaller than the proppant PSD mode,    and wherein the treatment fluid comprises from 0 to 3 parts by    weight dispersant, from 0 to 3 parts by weight surfactant, from 0 to    3 parts by weight defoamer, and from 0 to 15 parts by weight    viscosifier, per 100 parts by weight carrier fluid; and in intimate    admixture therewith, a fines emulsion comprising 1 to 5 micron    polylactide particles, an anionic surfactant and optionally a    plasticizer.-   261. The treatment fluid of embodiment 260, wherein the    Apollonianistic solids mixture further comprises an acid-reactive    fines having particle size distribution mode smaller than the second    PSD mode and comprising from 1 to 20 microns.-   262. A composition, comprising: a carrier fluid and dispersed    therein from 5 to 100 g per 100 ml carrier fluid of a fluid loss    control system comprising a mixture of surfactant-treated    hydrolyzable fines having a particle size distribution between 1 and    10 microns, and of submicron particles.-   263. The composition of embodiment 262, wherein the hydrolyzable    fines comprise a polymer or copolymer of lactic acid, glycolic acid,    or the combination thereof, emulsified or stabilized with a nonionic    or anionic surfactant.-   264. The composition of embodiment 262 or 263, wherein the submicron    particles comprise silica, γ-alumina, MgO, γ-Fe2O3, or a combination    thereof, or from the group consisting of silicates, γ-alumina, MgO,    γ-Fe2O3, TiO2, and combinations thereof.-   265. The composition of any one of embodiments 262 to 264, wherein    the carrier fluid is aqueous, the hydrolyzable fines comprise    polylactic acid having a particle size distribution between about 1    and about 5 microns emulsified or stabilized with an anionic    surfactant, and the submicron particles comprise silica, γ-alumina,    MgO, γ-Fe2O3, or a combination thereof, or from the group consisting    of silicates, γ-alumina, MgO, γ-Fe2O3, TiO2, and combinations    thereof, and wherein a weight ratio of the hydrolyzable fines to    submicron particles is from 1:3 to 3:1.-   266. A method, comprising: mixing an aqueous hydrolyzable polyester    emulsion and a carrier fluid to form a treatment fluid, and    circulating the treatment fluid into a wellbore.-   266A. The method of embodiment 266 wherein the aqueous hydrolyzable    polyester emulsion comprises polyester particles having a particle    size distribution between 0.1 and 10 microns-   267. The method of embodiment 266 or 266A, further comprising    introducing Apollonianistic solids into the treatment fluid.-   268. The method of any one of embodiments 266 to 267, further    comprising introducing proppant into the treatment fluid.-   269. The method of embodiment 268, further comprising forming a pack    of the proppant downhole.-   270. The method of embodiment 269, wherein the pack comprises    proppant and at least one particle size distribution mode comprising    degradable particles, and further comprising removing the degradable    particles from the pack to form a permeable proppant pack.-   270A. The method of embodiment 270, wherein the at least one    particle size distribution mode comprising degradable particles is    smaller than the proppant and larger than 20 microns.-   271. The method of embodiment 270 or 270A, further comprising    producing or injecting a fluid through the permeable proppant pack.-   272. The method of embodiment 270, embodiment 270A or embodiment    271, wherein the degradable particles comprise a polymer or    copolymer of lactic acid, glycolic acid, or the combination thereof.-   273. The method of any one of embodiments 270 to 272, wherein the    permeable proppant pack comprises a gravel pack in an annulus    between a screen and the wellbore.-   274. The method of any one of embodiments 270 to 273, wherein the    permeable proppant pack is disposed in a fracture.-   275. A method to inhibit fluid loss from a treatment fluid,    comprising introducing an aqueous hydrolyzable polyester fines    emulsion into the treatment fluid and introducing the treatment    fluid into a wellbore.-   276. A method to stabilize and inhibit fluid loss from a treatment    fluid, comprising introducing submicron particles and an aqueous    polylactic acid emulsion into the treatment fluid.-   277. A method, comprising fracturing a formation with a treatment    fluid comprising aqueous hydrolyzable polyester fines emulsion    comprising polyester particles having a particle size distribution    between 0.1 and 10 microns dispersed in a carrier fluid.-   278. The method according to any one of embodiments 275 to 277,    wherein the treatment fluid comprises a slurry comprising an    Apollonianistic solids mixture.

EXAMPLES Example 1

In this example, the effects of varying the size and concentration ofthe smaller particles in a 4-mode PSD system were investigated. A seriesof syringe fluid loss tests were performed where the particle size andconcentration of the second particle were varied. In these tests, thefirst particle was 20/40 CARBOLITE proppant (average diameter 770 μm),and the other particles were made of silica. The size and concentrationof the second particle were varied, the third particle had an averagediameter of 32 μm and the fourth particle had an average diameter of 3μm. A dry blend was made using the four particles by mixing 50 gCARBOLITE, x g of the second particle, 5 g of the third particle and 10g of the fourth particle, where x was 5.5 g, 7 g, 9 g or 12 g. The dryblend was made into slurry by adding 10.5 ml of DI water. Table 1 liststhe fluid loss observed in the syringe tests for the different slurries.

TABLE 1 Slurry Composition and Syringe Fluid Loss Data for Runs 1-1 to1-4 (Second Particle Size and Concentration Varied) Second Particle Run1-1 Run 1-2 Run 1-3 Run 1-4 Concentration, g (P1/P2/P3/P4) → 50/5.5/5/1050/7/5/10 50/9/5/10 50/12/5/10 Size (P1/P2/P3/P4 = 770/x/32/3, μm) SizeAverage Size, Mesh Range, μm μm LEAK-OFF (mL) −50/+60 250-297 274 ND ND5.90 ND −60/+70 210-250 230 ND ND 5.38 3.1  −70/+100 149-210 180 4.322.13 1.92 0.72 −100/+140 105-149 127 1.14 0.42 0.72 0.26 −140/+170 88-105 96.5 1.68 0.60 0.31 0.2 −170/+200 74-88 81 4.65 4.80 0.70 0.3−200/+230 63-74 68.5 ND 6.35 0.65 0.4 −230/+270 53-63 58 ND ND 3.28 0.57−270/+400 37-53 45 ND ND 5.50 3.35 ND = Not Determined

The data are plotted in FIG. 4 as a function of the second particlesize. As illustrated in FIG. 4, high concentrations of the secondparticle relative to the first particle can allow a broader range of theaverage size of the second particle to be used to reduce leak-off.However, a carefully selected second particle size can allow lowerconcentrations of the second particle to be used, potentiallyfacilitating clean up or removal of the smaller particles to convert thepacked particles from the slurry into a porous, permeable gravel/orproppant pack. For example, at 12 g of the second particle per 50 g20/40 CARBOLITE first particles, an average second particle sizeanywhere between 60 μm and 180 μm effectively bridged the gap betweenthe 20/40 CARBOLITE particles leading to low leak-off. As theconcentration of the second particle was reduced to 5.5 g, however, thesecond particles in the average size range between 100 μm and 150 μmcontrolled leak-off, with an optimum particle size of about 127 μm+/−10or 15 μm. This example shows that the ratio of the average sizes of thefirst to second particle in this example is beneficially within therange of about 770/(127+15)˜5.4 to about 770/(127−15)˜6.9, or from about5.6 to about 6.6, or equal to about 770/127˜6.06.

Another series of tests were then run using the 127 μm second particlewhile varying the size of the third particle as shown in Table 2 below.

TABLE 2 Slurry Composition and Syringe Fluid Loss Data for Run 1-5(Third Particle Size Varied) Third Particle Run 1-5 Concentration, g(P1/P2/P3/P4) 50/7/3/10 Size (P1/P2/P3/P4 = 770/127/x/3, μm) SizeAverage Size, LEAK-OFF Mesh Range, μm μm (mL) −140/+170  88-105 96.57.78 −200/+230 63-74 68.5 1.3 −230/+270 53-63 58 0.58 −270/+400 37-53 450.97 27-37 32 1.55 11 7.84

The data are plotted in FIG. 5 as a function of the third particle size.The plot shows that the lowest leak-off rate at this concentration wasobtained for the 58 μm third particles, establishing a range of theratio of the second particle average size to that of the third particleof from about 2.0 to about 2.4, ideally about 2.18.

An approximate packing model for the particle size ratios according toone embodiment is seen in FIG. 6, which was obtained using the Descartescircle theorem. For four mutually tangent circles with curvatures,P_(n), P_(n+1), P_(n+2), and P_(n+3), the following equation (1) isapplicable:

$\begin{matrix}{{\frac{1}{P_{n}^{2}} + \frac{1}{P_{n + 1}^{2}} + \frac{1}{P_{n + 2}^{2}} + \frac{1}{P_{n + 3}^{2}}} = {\frac{1}{2}\left( {\frac{1}{P_{n}} + \frac{1}{P_{n + 1}} + \frac{1}{P_{n + 2}} + \frac{1}{P_{{n + 3}\;}^{\;}}} \right)^{2}}} & (1)\end{matrix}$where P_(n) is the curvature of circle n, where curvature is taken asthe reciprocal of the radius. For example, when three equally sizedspheres (Size P1=1) are touching each other, the size (diameter) ratioof P1/P2 can be obtained using the above equation to be 6.464˜6.5.Similarly, the other ratios for the particle sizes required to stopleak-off in an embodiment can be estimated as P2/P3 being about 2.5 andP3/P4 being about 1.8, and when a fifth particle is used, P4/P5 is about1.6. As a practical matter it can be difficult to obtain and/or workwith particles having an average size range less than about 10 μm at theaccuracy required, and one embodiment compensates by using a relativelylarge proportion of the fourth particle wherein the fourth particle hasan average size between 10 and 20 μm.

Example 2

In this example the stability of a slurry was qualitatively observed byaging the slurry in a glass bottle under static conditions for 48 h inthe temperature range of 66° C. (150° F.) to 121° C. (250° F.). At theend of 48 h, a pipette was manually inserted into the slurry to gaugethe force required to stab into the slurry. This was a qualitative testand the force required to stab in was assigned a number from 0 to 5 with0 being the worst case (cannot stab in) and 5 being the best case. Afterthe stab-in test, the slurry was poured out of the bottle to check theflow properties and settling at the bottom of the slurry. Theflowability was also assigned a number between 0 and 5, where 0 refersto not flowable and 5 refers to flowable slurry.

In Runs 2-1 to 2-3 a four-particle slurry as shown in Table 3 wasevaluated at 66° C., 93° C. and 121° C. using diutan (0.036 wt %) as aviscosifier in the liquid phase.

TABLE 3 Slurry Compositions and Stability Results with Diutan SlurryStabilizer Component/Property Run 2-1 Run 2-2 Run 2-3 Temperature, C. 6693 121 CARBOLITE (20/40, 620 μm), g 100 100 100 Silica (200 μm), g 12 1212 Silica (32 μm), g 30 30 30 Silica (3 μm), g 32 32 32 DI Water, g 2323 23 Diutan, g 0.008 0.008 0.008 Slurry Stability Results, 64 hStab-In, scale 0-5 5 5 5 Flow, scale 0-5 4 4 4 Settling yes yes yes

After 64 h at temperature, it was easy to stab-in a pipette into theslurry and also to pour the slurry out of the bottle. However, asediment was observed in the bottle. In Run 14-4, a four-particle slurryas shown in Table 17 was evaluated at 121 C using nanometer sizedγ-alumina (40 nm, obtained from Infarmat Advanced Materials) as a slurrystabilizer.

TABLE 4 Slurry Composition and Stability Result with γ-Alumina SlurryStabilizer Component/Property Run 14-4 Temperature, C. 121 CARBOLITE(20/40, 620 μm), g 100 Silica (200 μm), g 12 Silica (32 μm), g 30 Silica(3 μm), g 32 DI Water, g 26 γ-Al2O3, g 0.008 Polynaphthalene sulfonate,ml 0.17 Slurry Stability Results, 86 h Stab-In, scale 0-5 5 Flow, scale0-5 5 Free water No Settling Little

The stab-in, flow and free water results showed that the stability ofthe slurry was much better than that formulated with diutan. A uniqueproperty of slurries formulated with γ-alumina is that they do not havea layer of free water at the end of the experiment.

In Run 2-5, a four-particle slurry as shown in Table 5 was evaluated at121° C. using gellan particles at 0.2 wt % and diutan at 0.036 wt %. Atroom temperature, the gellan particles dispersed easily in water but didnot increase the viscosity of the mixture. At temperatures above 90° C.,the gellan particles hydrate, increasing the viscosity of the solution.This is a very useful property in one embodiment because the particlescan be added to the slurry at the surface without increasing theviscosity. After the slurry is placed downhole, the decrease inviscosity of liquid phase due to temperature can be compensated by theincrease in viscosity due to hydration of gellan particles.

TABLE 5 Slurry Composition and Stability Result with Gellan/DiutanSlurry Stabilizer Component/Property Run 2-5 Temperature, C. 121CARBOLITE (20/40, 620 μm), g 100 Silica (200 μm), g 12 Silica (32 μm), g30 Silica (3 μm), g 42 DI Water, g 28 Diutan, g 0.01 Gellan gum, g 0.06Slurry Stability Results, 86 h Stab-In, scale 0-5 5 Flow, scale 0-5 5Free water Yes Settling No

The results in Table 5 showed that the slurry was stable and did notshow settling at the end of the experiment.

In Runs 2-6, 2-7 and 2-8, the gellan/diutan, four-particle slurry ofTable 5 was evaluated at different temperatures after 48 h as shown inTable 6.

TABLE 6 Stability Result with Gellan/Diutan Slurry Stabilizer SlurryStability Results, 48 h Run 2-6 Run 2-7 Run 2-8 Temperature, ° C. 66 93121 Stab-In, scale 0-5 5 5 5 Flow, scale 0-5 5 5 5 Free water No No NoSettling No No No

The results in Table 6 showed that the slurry was stable when the fluidphase is viscosified at high temperature with gellan gum.

In Run 2-9, a four-particle slurry as shown in Table 7 was evaluated at121° C. using polylactic acid (PLA) flakes to improve stability. Thefluid phase of the slurry was not viscosified with diutan. The averagesize of the PLA flakes was around 1 mm.

TABLE 7 Slurry Composition and Stability Result with PLA SlurryStabilizer Component/Property Run 2-9 Temperature, ° C. 121 CARBOLITE(20/40, 620 μm), g 100 Silica (200 μm), g 12 Silica (32 μm), g 30 Silica(3 μm), g 32 DI Water, g 26 PLA Flakes, g 2 Slurry Stability Results, 86h Stab-In, scale 0-5 5 Flow, scale 0-5 5 Free water Yes Settling Little

The results in Table 7 showed that the addition of PLA flakes improvedthe stab-in, flow and settling properties of the slurry when compared tothe stability results of the slurry formulated with diutan as shown inTable 3.

Example 3

The design of a high-solids slurry using a PLA fines emulsion for fluidloss control was investigated. The proppant was 40/70 mesh sand, and theintermediate particles were degradable polylactide (PLA) with PSD's of45 and 90 microns. The PLA fines emulsion was a LANDY PL Series PL-2000polylactide (NATUREWORKS biopolymer) resin emulsion for obtainedcommercially from Miyoshi Oil & Fat Co., Ltd., described as a 40 wt %solids emulsion of 2 μm PLA particles with a weakly anionic ioniccharacter, viscosity 1000 mPa-s, normally used for coating and adhesiveapplications. The formulations included ANTAROX 31R1 surfactant(Rhodia), AMPS/acrylamide copolymer as a polymer viscosifier,polysiloxane defoaming agent, and fumed silica. Runs were prepared withand without 2 μm calcium carbonate fines, and with and withoutpolynaphthalene sulfonate dispersant. Multimodal slurries were preparedusing the compositions in Table 8. The ability of the slurry to inhibitleak-off into a screen under high differential pressure conditions wasinvestigated. These experiments were conducted in a commercial hightemperature, high pressure (HTHP) fluid loss cell by placing a ceramicdisk having 10-μm openings at one end of the cell and loading the slurryon top of the disk. The leak-off tests were conducted by applying 3.45MPa (500 psi) differential pressure with N2 gas for a period of 60minutes at room temperature (24° C.). The rheological and leak offcontrol properties are shown in Table 8.

TABLE 8 Slurry Composition and Spurt Results for Runs 3-1 to 3-3Component Run 3-1 Run 3-2 Run 3-3 40/70 Mesh Sand (300 μm), g 386.9 406372.1 PLA (90 μm), g 47.9 53.9 49.4 PLA (45 μm), g 47.9 53.9 49.4 CaCO3(2 μm), g 45.4 0 0 PL-2000 40 wt % PLA 35.2 35.2 59.4 Emulsion (2 μm), gPolynaphthalene sulfonate, g 1.2 1.2 0 ANTAROX 31R1 Surfactant, g 1.41.35 1.24 AMPS/Acrylamide Copolymer 4.6 4.6 5.15 (viscosifier), gPolysiloxane (defoamer), g 0.9 0.9 1 Fumed silica, g 9 9 20.2 DI Water,g 114 114 102.2 Rheological Properties Free Fluid after 1 h, visuallittle little little Plastic Viscosity, mPa-s 1250 1400 839 YieldStress, Pa 8 8.8 15 Leak-Off Control Properties Spurt, g 0.56 1.08 0.91Leak Off (3.45 MPa, 30 min) 2.58 2.9 2.2 Leak Off (3.45 MPa, 60 min)3.38 3.7 2.78 Clean-Up Properties Spurt, g >200

All three fluids were stable as indicated by little free fluid after 1hour of observation. Runs 3-1 and 3-2, prepared with CaCO3 particlesand/or dispersant and less PLA emulsion and less fumed silica relativeto Run 3-3, had similar rheological properties and leak off controlproperties, indicating that CaCO3 and/or dispersant may be optionallyused. All runs had excellent stability, good rheological properties fordownhole pumpability and very good leak-off control properties.

After performing the ambient temperature leak-off experiment in Run 3-1,the HTHP test cell was depressurized and heated to 121° C. (250° F.) toallow the PLA to degrade and the resultant acid to react with thecalcium carbonate particles, leaving the porous sand pack. The systemwas cooled back to room temperature, and when the same pressure wasapplied to the fluid loss cell, the fluid quickly leaked off in lessthan one minute. This result indicates the fluid loss control agent,fines and smaller particles in this system are effectively removed atelevated temperature.

While the embodiments have been illustrated and described in detail inthe drawings and foregoing description, the same is to be considered asillustrative and not restrictive in character, it being understood thatonly some embodiments have been shown and described and that all changesand modifications that come within the spirit of the embodiments aredesired to be protected. It should be understood that while the use ofwords such as ideally, desirably, preferable, preferably, preferred,more preferred or exemplary utilized in the description above indicatethat the feature so described may be more desirable or characteristic,nonetheless may not be necessary and embodiments lacking the same may becontemplated as within the scope of the invention, the scope beingdefined by the claims that follow. In reading the claims, it is intendedthat when words such as “a,” “an,” “at least one,” or “at least oneportion” are used there is no intention to limit the claim to only oneitem unless specifically stated to the contrary in the claim. When thelanguage “at least a portion” and/or “a portion” is used the item caninclude a portion and/or the entire item unless specifically stated tothe contrary.

We claim:
 1. A method, comprising: mixing a treatment fluid comprising:a solids mixture having an Apollonianistic particle size distribution(PSD) comprising proppant slurried in a carrier fluid; a fluid losscontrol agent comprising an aqueous hydrolyzable polyester finesemulsion; and submicron particles comprising γ-alumina, MgO, γ-Fe2O3,TiO2, and combinations thereof; circulating the treatment fluid into awellbore.
 2. The method of claim 1, further comprising forming a pack ofthe solids downhole.
 3. The method of claim 2, wherein the packcomprises proppant and at least one particle size distribution modecomprising degradable particles, and further comprising removing thedegradable particles from the pack to form a permeable proppant pack. 4.The method of claim 3, further comprising producing or injecting a fluidthrough the permeable proppant pack.
 5. The method of claim 3, whereinthe degradable particles comprise a polymer or copolymer of lactic acid,glycolic acid, or the combination thereof.
 6. The method of claim 3,wherein the permeable proppant pack comprises a gravel pack in anannulus between a screen and the wellbore.
 7. The method of claim 3,wherein the permeable proppant pack is disposed in a fracture.
 8. Themethod of claim 1, wherein the hydrolyzable polyester fines emulsioncomprises polyester particles having a particle size distribution modefrom about 0.1 to 20 microns.
 9. The method of claim 1, wherein thehydrolyzable polyester fines emulsion comprises polyester particles anda surfactant.
 10. The method of claim 1, wherein the solids mixturecomprises an acid-reactive fines particle size distribution mode.